overall yield of products (volume)

Overall Yield of Products (Volume)

Product Yield Base Delayed LC-LC-MAX

on Crude, Vol % Refinery Coking FINING

LPG 3.8 5.0 4.7 5.3

Naphtha 9.2 14.5 12.6 13.7

Gasoline 13.3 12.5 12.4 12.7

Jet 15.0 15.0 15.0 15.0

Diesel 35.9 52.2 49.0 56.5

C3+ Distillate Yield, Vol % 77 99 94 103

0.5% S Fuel Oil

1.5% S Fuel Oil 10.9


Asphalt 5.0 3.0

Fuel Grade Coke 5.6 (FOE)

Volume Gain,% on Crude 1.98 -0.8 4.66 6.30

Chevron • CONFIDENTIAL PROPERTY OF CHEVRON LUMMUS GLOBAL

TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF CHEVRON LUMMUS GLOBAL

Chevron Lummus Global

Lummus Technology 20 a CB&I company

Overall Yield of Products (Weight)

Product Yield Base Delayed LC-FINING on Crude, Wt % Refinery Coking

LPG 2.4 3.2 3.0

Naphtha 7.1 11.3 9.9

Gasoline 11.3 10.8 10.7

Jet 13.5 13.6 13.6

Diesel 34.3 49.7 46.9

C3+ Distillate Yield, Wt% 69 89 84



Asphalt 6.0

Fuel Grade Coke 7.4




LC-MAX

3.3

10.8

11.0

13.7

53.8

93

3.8


Summary of Incremental Capacities

Chevron •

Capacity

Delayed Coking, BPD

LC-FINING, BPD

LC-MAX, BPD

Hydrocracking, BPD

Distillate HT, BPD

Hydrogen Plant, MMSCFD

Sulfur Recovery, TPD

Delayed I Coking I

37,600

13,900

20,400

34

121

CONFIDENTIAL PROPERTY OF CHEVRON LUMMUS GLOBAL

I

LC-FINING

38,300

9,500

16,600

73

212



LC-MAX

36,400

26,000

23,000

103

237


Upgrading Economics 2,500

ER-::!: 2,000 ::!: > a. 1,500 z ER- 1,000 ::!: ::!: 500 u I-

0 Delayed Coking

- TIC,MM$ 1,047

- NPV,MM$ 1,265

-O-IRR, % 29.1

MD Yield wt% 63

LC-FINING

1, 115

1,590

31.1

61

LC-MAX

1,443

2,269

32.3

79


33.0

32.0

31.0 '?fe. £i

30.0 0:::

29.0

28.0

Economics are incremental to Base Refinery, Debt/Equity=0/100, 30% tax rate, 4 years of construction, straight-line depreciation over 15 years of project economic life, and 15% discount rate for NPV calculations




LC-MAX Process Summary Chevron Lummus Global

• Process concept has been proven and is ready for commercialization

• Maximizes residue conversion to -85 wt 0/o

• Increases flexibility to handle more difficult feeds

• Reduces dependency of conversion on type of feed processed

• Rejects heavy asphaltenes from process

• Reduces reactor volumes, catalyst and hydrogen consumption

• Has very attractive return on investment

• Process can be applied to revamp and grassroots scenarios Chevron • CONFIDENTIAL

PROPERTY OF CHEVRON LUMMUS GLOBAL TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF CHEVRON LUMMUS GLOBAL


Clean Green Hydrocracking Machine Article

Clean, green, hydrocracking m.achine Dan Torchia, Arun Arora and Luyen Vo, Chevron Lummus Global, USA, offer an overview of the hydrocracking technology advancements that provide creative ways to meet the clean fuels challenge.

H ydrocrackers have always produced environmentally friendly fuels, even before environmental regulations on refined products increased. No other process can take low va lue, highly aromatic, high

sulfur and high nitrogen feedstocks and produce a full slate of desirable sweet products: LPG, high quality diesel fuel. hydrogen rich FCC feed, ethylene cracker feed and/or premium lube unit feedstocks.

Modern hydrocracking was commercialised in the early 1960s. These original units converted light feedstocks (from atmospheric crude towers) into high value, high demand gasoline products. In addition, high hydrocracker volume gain (exceeding 20%) added significantly to the refinery bottom line. Due to these strong attributes, hydrocracker capacity has increased stead ily over the years (Figure 1).

Increased environmental regulations on gasoline and diesel

have made hydrocracking an essential process, resulting in ever

greater increases in worldw ide capacity. The most recent

grassroots hydrocrackers were designed to maximise the

production of middle distillates from increasingly difficult

feedstocks such as FCC light cycle oil (LCO), heavy vacuum gas

oils (HVGO) and heavy coker gas oi ls {HCGO). Like their

predecessors, most modern hydrocrackers produce high value,

environmentally friend ly distillate products, including massive

vo lumes of ultra low sulfur diesel (UL.SD), even with

progressively more demanding feedstocks (Table 1). Early generation hydrocrackers had capacities of

approximately 10 000 bpd, while many new units today exceed

100 000 bpd.

Catalyst advancements Ongoing market growth, ever increasing operating severities and

the design of very large units has propelled Chevron Lummus

Global (CLG) towards an ambit ious catalyst development

programme, especially over the last decade.

Each new catalyst lowers the reactor temperature required

to achieve target conversion (extends run length), while

Table 1. Hydrocrackers: then and now

1960s 2000s

Average unit size (bpd) 10-20 000 50 - 60 000+

Feed S (wt%) 0.5 -1.0 2.0 - 3.0

Feed N (ppmw) 500 -1000 2000+

Feed % cracked 10-20 25-70

Primary product Naphtha/ Jet Jet/Diesel

Naphtha S (ppmw) 0.5 - 10 0.5-5

Diesel S (ppmw) 100-500 5 -10

Table l. Comparison ofhydrocracker flow schemes

Single stage once SSREC through

Capacity restrictions for single 65 - 70 000 ·50 000 train, fresh feed basis (bpd]

Maximum commercial conversion (%)

80

Segregated reaction zones No

NH3 and ~S inhibition effect on Yes cracking and aromatic saturation

Middle distillate selectivity at Base - - -

97- 99

No

Yes

Base - -

maintaining the product slate or, conversely, improves the

product yield structure at target activity and run length. W ith

improvements to catalyst formulations and raw material quality

(both amorphous and zeolitic), CLG's latest line of

ISOCRACKING'" catalysts can enhance selectivity for a full range

of applications, and also exhibit increased activity and stability

for processing increasingly difficult feedstocks. These catalyst

developments demonstrate high stab ility in processing heavy and

cracked feeds with nitrogen contents exceeding 3000 ppmw.

Along with optimum catalyst design, catalyst l ife cycles can

be extended by improving reactor operation. CLG's ISOMIX"'-e

reactor internals enhance reactor operation by thoroughly

mixing and uniformly distributing gas and liquid across the

reactor bed, while also allowing for complete wetting of the

catalyst. This results in even temperature d istribution (low radial

ii Ts) and maximum catalyst utilisation across t he reactor bed,

improving cycle length and operating stability. With its unique

truss system structure to support the reactor internals, catalyst

volume can be increased allowing for longer cycles, higher

throughput and faster turnarounds, all with minimal capital

investment. This combination of linked catalyst and hardware

design is essential for the rel iable production of maximum clean

fue ls today.

Process advancements The growing demand for middle d istillates, a declining market

for high sulfur fuel oil, and increasingly stringent environmental

regulat ions are putting refineries, especially those with lower

Nelson complexity index, under immense margin pressures and

even forcing many to shut down. Th is recent trend has led t o

grassroots projects for distil late oriented conversion

technologies. Very few (if any) refineries have their conve rs ion

strategy focused on FCC technology, and many FCC units are

operating in low severity distillate mode or occasionally being

converted to a propylene producer ..

TSREC and optimum Single stage reverse conversion sequence

65 -70 000 50 - 55 000

100 for TSREC and 100 70 - 80% for OPC

Yes Yes

No No

Base Base-maximum conversion (80% conversion) (99% conversion) (100% conversion) (100% conversion)

Operating pressure for same run Base ++

length at maximum conversion

Feed flexibility at design capacity

Product flexibility

Total installed cost at maximum conversion

Very poor (conversion)

None exceptfinal distil lation

Base+ at 80%

· • HYDROCARBON Reprinted from June 2012 ENGINEERING

Base+

Moderate (PPC, overall conversion)

Moderate (change RCP or PPC)

Base .++ for >60 MBD Base+ for30 -40 MBD Base - for <30 MBD

Base

Very good (shift ' conversion, PPC in 2nd stage)

Very good (change conversion, RCP, PPC in 2nd stage)

Base

Base



Base-

Hydrocracking offers greater flexibility to process

opportunity crudes while producing premium grade clean fuels,

which improve refinery margins. Thus, in the last decade alone,

more than 90 hydrocracking units have been licensed

worldwide. Many new refineries and refinery expansions are

targeting operating capacities of 400 000 bpd or higher: which

in many cases increases average hydrocracker capacity

beyond the conventional 65 000 bpd single train capacity to

70 000 bpd. CLG has designed several units ranging

70 000 - 140 000 bpd; one of these is currently in

precommissioning, one is under construction, and others are in

the advanced engineering stages.

1000 t--------0 ,, .. 1'98 2002 2006

Figure 1. Worldwide hydrocracking capacity (million bpd). Source: Oil & Gas Journal Annual Refining Surveys, 1986 - 2011.

1

. F.u .... --~lttlUI . ...., Nepi'llh.a ll;etOHM

•Dfn•t

I

Figure 2. Scheme one, process flow.

Table J. Unit performance

2010

Recent commercial experience shows that most of the high

conversion, world scale units processing difficult feedstocks

have opted for t he two stage recycle (TSREC) process

configuration. These units generally feed high nitrogen VGO and

coker gas oils while maximising middle distillates production.

The flexibil ity to independently adjust stage one and stage two

conversion based on feed quality and product requirements is

simply not possible in single stage recycle [SSREC)

configurations. For example, for poor quality and/or more

refractory feeds, it may be beneficial to reduce stage one

conversion to the minimum required to meet the nitrogen

target for stage two feed, result ing in a lower catalyst

deactivation rate in stage one. This shifts the load to stage two,

where the increased severity can be handled because it operates

in an NH3 and H2S free atmosphere, and has a significantly

reduced deactivation rate. In addition, the TSREC process flow

scheme also offers:

• The capability to increase conversion in stage one (up to

60%) for processing simpler feeds to maximise the yield of

middle d istillates.

• Minimum product quality giveaway by optimising conversion in stage one and stage two.

• Up to 10% lower hydrogen consumption compared to SSREC configuration (higher selectivity).

• Lower total installec cost compared to SSREC configuration due to smaller reactors.

CLG has over 30 operational TSREC hydrocracking units with

capacity ranging 20 000 - 60 000 bpd. Table 2 presents a

summary evaluation of the various processing schemes. This

evaluation of hydrocracking shows that, at higher conversion

levels (over 80%) and at higher capacities (over 50 000 bpd),

TSREC is the most economically attractive configuration.

Clean fuels from heavy feeds tocks Two innovative hydrocracking schemes for clean fue ls

production are presented as follows:

• Scheme one presents a modified TSREC scheme to process

refractory feeds such as HCGO and HVGO. The objective Is

to maximise diesel with severe cold flow property

specifications, along with providing the flexibility to

produce feed for group Ill lube base oils production.

• Scheme two presents CLG's latest patented scheme for

residue hydrocracking, called LC-MAX. This technology will

permit refiners to convert over 85% of the vacuum

residue to VGOs and lighter material, even while

Mid distillates in fuel mode

UCO in lube mode processing the most difficult feeds. The process is

particularly attractive when a ref iner has an existing

delayed coking unit that requires debottlenecking or Yield(%) 93 (Summer): 88 (Winter) 12

S(ppmw) <6 <10

N (ppmw} <1 <2

Pour point (0 C) -13 (Summer); -30*

{Winter)

Cetane index >53 (Summer}; >48 (Winter)

Waxy (VI) >140

Run length 36 months 36 months

*The unit is designed to produ'e a 'ertain amount of Arctic Diesel with a pour point <-45 •c by lowering the re'Yde cut point {RCP) to se,ond stage

when tightening margins requ ire the refiner to

process opportunity crudes.

Scheme one

Produce clean fuels and group /// base oils while processing cracked feedstock This process ing scheme is designed for HVGO from

West Siberian and Sakhalin crudes, and HCGO to

maximise the production of Euro V diesel. This also

offers an option to produce feed for the group 111

lubes (Figure 2). The unit is integrated with a

HYDROCARBON • . tNGINEERING Reprinted from June 2012

hydrotreating urnt to upgrade distillates using the CLG patented split feed injection technology. HVGO and HCGO are processed in parallel first stage reactor systems with a shared second stage. When the unit operates in fuels mode. the unconverted oil (UCO) from the VGO section is mixed with UCO from the HCGO section and hydrocracked to extinction in the common second stage. In base oil production mode, the UCO bleed is fed to the lube oil unit.

The catalyst system selected for the reactor processing as much as 65% HCGO was primarily Ni-Mo hydrotreating followed by one of CLG's latest high activity middle distillate selective hydrocracking catalysts. The reactor processing HVGO is loaded with high middle distillate selective hydrocracking catalyst. The catalyst system is tailored for increasing the visoosity index (VI) of the UCO to a level where, after CLG licensed ISODEWAXING technology is applied, group Ill base oils can be produced. The second stage is loaded with a high distillate selective. high hydrogenation function, second stage catalyst. Table 3 provides the key performance parameters for this scheme.

Scheme two

Clean fuels from residue hydrocracking utilising the LC-MAX process This scheme offers an advantage over conventional LC-FINING (Table 4) by offering conversion levels of 85+%, even for very difficult residuum. Whole vacuum residue is processed in the first reaction stage and UCO from the first stage is deasphalted in the solvent deasphalting unit (SDA) to remove heavy asphaltenes. The intermediate step of removing asphaltenes offers large savings in hydrogen consumption, which would otherwise have been used to saturate and crack these difficult molecules. Clean deasphalted oil (DAO) from the SDA step is

RHkl -- ··---

' I~::;. I-· -~----Armotplterir: I I Ddfi&fn

.•. , J RkhT~u Ou l.=:=:__I ~~ Vxuum

•

Olri:lfalH

. ~·~•m iR•MIH . .... ~. MO

-Figure l . LC-MAX simplified flow scheme.

Table 4. Comparison of LC-FINING with LC-MAX

Stand alone LC-MAX first LC-MAX LC-FINING stage second stage

Flow rate Base Base 0.4 Base

Reactor temperature (" C) Base +10 +28

Reactor volume Base 0.45 Base 0.35 Base

Chemical H2 coins Base 0.7 Base 0.4 Base

Catalyst addition rate Base 0.75 Base 0.13 Base

. • HYDROCARBON Reprinted from June 2012 ENGINEERING

hydrocracked at much higher reaction rate in the second stage. Improved reaction rates in the second stage greatly reduce the required reactor size and catalyst addition rate (Table 4). With the second stage now available to achieve conversion at higher reaction rates, first stage conversion can be limited to 48 - 60% to limit sediment formation. limiting conversion in the fi rst stage also permits operation at relatively high space velocity, thereby offering savings in the reactor size.

Furthermore, by processing DAO, the second stage processing operates at 80 - 95% conversion with negligible seciment formation. This reduced sedimentation also increases the operating factor by minimising the risk of back end equipment foul ing. The pitch from the SDA can be fed to a coker. burned in a gasifier, fed to a pelletiser, blended to make bunker fuel or burned as a fuel with cutter stock. A recent study for a refiner with a 40 000 bpd LC-MAX unit showed that 165 tpd of hydrogen or 165 MW of power can be generated by feeding pitch to a gasifier.

The VGO and lighter products from the LC-MAX process can be upgradec within the same high pressure loop as the LC-MAX process using the integrated hydroprocessing concept first commercialised by CLG for a major refiner in Canada, and again in Northern Europe. The basic process flow for this scheme is illustrated in Figure 3.

Trend towards cleaner fuels The global push towards clean fuels is in full swing as more and more countries impress stricter policies onto fuels in order to reduce their carbon footprint. Over the next 20 years the global energy demand is expected to rise by almost 40%, with most of this demand growth occurring in developing countries such as China and India. Coupled with this demand will be an even greater drive to reduce carbon emissions with cleaner fuels, as well as a bigger push to increase the blending targets for biofuels and renewable fuels into the fuels market. In essence, it will be increasingly more difficult to meet clean fuels requirements.

With the majority of emissions coming from on road

vehicles, the mandates around clean fuels and emissions reduction also impact the lubricants market, where formulators are now required to produce engine oils and transmission fluids with lower volatility and enhanced oxidation stability. as well as contributing to better fuel economy. Formulators have had to shift from group I to more group 11/111 base oils in order to meet these requirements. Group I base oils are t rad itionally produced by solvent refining. whereas group 11/111 base oils are produced using an all hydroprocessing route that utilises hydrocracking to meet viscosity index, sulfur and aromatics requirements. As such, CLG hydrocracking and hydroprocess1ng technology is favourably

positioned for both clean fuels and high quality base oils. With the proiectec rise in energy demand and continued

trend towards cleaner fuels, global hydroprocessing capacity is expected to increase to meet the challenge. In the long term, refiners must continue to look for creative ways to boost refining margins with low value feedstocks while meeting the changing clean fuels requirements. QG's innovative and cost effective hydroprocessing technology solutions are expected to continue to deliver clean fuels to the marketplace for the foreseeable future. /!ll

Eco-friendly Residue Upgrading Technologies for Refineries Article

American International Journal of Research in Science, Technology, Engineering & Mathematics

Available online at http://www.iasir.net

ISSN (Print): 2328-3491, ISSN (Online): 2328-3580, ISSN (CD-ROM): 2_32_8~-3_6_2_9-----------

AIJRSTEM is a refereed, indexed , peer-reviewed, multidisciplinary and open access journal published by International Association of Scientific Innovation and Research (IASIR), USA

(An Association Unifying the Sciences, Engineering, and Applied Research)

Eco-friendly Residue Upgrading Technologies for Refineries

Huma \Varsi Khan1• · Moina Athar2

, MS Kamna' 1 Department of Chemical Engineering,

I.E.T M J P Rohilkhand University Bareilly, INDIA. 2 Department of Petroleum Studies,

AMU, Aligarh, INDIA.

Abstract: With the increase in population, the demand of useful refine1y products is also increasing. As demand is increasing, production and use of these refine1y products is giving rise lo harmful emissions resulting in various problems for environment as we!I as humans. This growth in demand - coupled with increasingly stringent sulfur content specifications, is leading in the direction of a shortage in refine/JI products -particularly those of lower sulfur contents. Jn order lo reduce emissions eco -fi'iendly upgrading rechnologies are needed. This led to the development of eco-friendly refi.ne1J1 technologies which are suitable for transforming these residues into more usefid products and also these processes are environmentfi-iendly. The main objective of these residue upgrading technologies the pre-treatment of feedstock for other conversion units, increasing distillates and the production of fuels with a low sulphur content. The major upgrading technologies are Hydrodesulph11risation, Delayed coking, LC-FINING, Residue desulphurization Process, and Solvent deasphalting. These processes are used for upgrading the residue. Also at the same they remove the hannful contaminants such as metals, sulphur, nitrogen etc. which leads to harmful emissions. Keywords: Residue upgrading technologies, LC Fining, LC Max

I . Introduction The demand for refined products is increasing worldwide and also is projected to increase significantly in the next 20 years, driven by population growth, and transition of emerging markets into the global economy. Production and use of these refinery products is giving rise to harmful emissions resulting in various problems for environment as well as humans. In order to reduce emissions eco-friendly upgrading technologies are needed. This led to the development of eco-friendly refinery technologies which are suitable for transforming these residues into more useful products and also these processes are environment friendly. The maj or upgrading technologies are Hydrodesulphurisation, Delayed coking, LC-FINING, Residue desulphurization Process, and Solvent deasphalting. These processes are used for upgrading the residue. Also at the same they remove the harmful contaminants such as metals, sulphur, nitrogen etc. which leads to harmful emissions. These technologies will also allow these refineries to process larger quantities of heavy, high sulfur, lower priced crudes, resulting in increased profitability.

II. Residu e Upgrading T echnologies The residue upgradation technologies are developed with a good on-stream factor, to maximise the mo st valuable product, to handle more difficult crudes and are environmentally compliant to meet future stringent specifications [1][2]. The major Upgrading technologies are: Hydrodesulphurisation, Delayed coking, LCFINING, Residue Desulfurization(RDS), Solvent Deasphalting(SDA).

A. Delayed Coking The most widely used residue conversion technology is Delayed Coking. This is particularly valuable when a long-term off take arrangement for coke exists. This is the primary residue conversion process for almost all the refineries all over the worlds except the refineries in Scandinavia, Western Europe, and Eastern Canada, where coking units are not preferred. Advantages of this process are that it can handle very poor quality feed i.e that contains high percentage of contaminants, and also in this process there is no residual product left for tl.irther treatment, and also this process is favourable in low price environment[2].

AIJRSTEM 13-334; © 2013. AIJRSTEM All Rights Reserved Page 71

H. Khan er al .. Am erican Intenrntimrnl Journal of Research in Science, Technology. Engineering & Mathematics. 4(1), SeptemberNovember, 2013. pp. 71-73

Fig. 1. Flow diagram of Delayed Coking

H••ter fl rac;.Uonator • • 0 I R eflux !J lr lpl'•• Drv m

1 I

B. LC Fining Process

Un•la"llLaed Naphtha

L!IM10M Oll

M•WV c .. 011 I

The LC-FINING process is a residuum conversion process that hydrocracks the most difficult, heavy, lowervalue hydrocarbon streams such as petroleum residua, heavy oils from tar sands, shale oils, etc., to lighter more valuable products such as VGO, diesel , and naphtha. The process feanires high distillate yields and high heteroatom and metals removal, and is an efficient way of handling petroleum bottoms and other heavy hydrocarbons. The LC-FINING process hydrocracks heavy vacuum residue feeds to lighter distillates while simultaneously removing sulfur, nitrogen, micro-carbon residue (MCRT), and metals containing species.

C. Residue Desulplmrisation Process Residue Desulfurization is a fixed bed process that has multiple beds of catalyst to remove metals, nitrogen and sulphur from petroleum residua in the presence of hydrogen. The process is normally used to produce low sulphur fuel oil or to produce a feed stream that is suitable for cracking in a residue FCC (RFCC) unit. D. Solvent Deasplwlting Process When the residue contains high concentration of asphaltene, which can be solvent deasphalted by a separation process called Solvent deasphalting [5][6]. Solvent deasphalting (SDA) is a unique separation process in which residue is separated by molecular weight (density) instead of by boiling point. Solvent deasphalting has the advantage of being a relatively low cost process that has flexibility to meet a wide range of DAO qualities. Solvent Deasphalting Process is useful in recovering large quantities of high quality oils which can be further upgraded via traditional FCC and Hydrocracking units [3]. E. LC 1l!lax Process CLG developed the LC-MA,'( process to alleviate conversion constraints resulting from feedstock quality and/or fractionator fouling limitations. This process combines LC-FINING and solvent deasphalting (SDA) in an integrated hydroprocessing configuration. With LC-MAX residue conversions ranging from a minimum of 80 up to 90 percent can be attained, even when processing very difficult high sediment forming feeds such as Russian Export crude (Urals) or South American and Canadian heavy crudes like Hamaca or Cold Lake [4] The LC-MAX process provides an efficient cost effective solution for achieving high residue conversions. By rejecting asphaltenes in the SDA pitch residue conversions of 85 volume percent can be attained even when processing very difficult high sediment forming opportunity crndes. With LC-MA,'( high conversion levels can be attained with reduced reactor volume, catalyst addition rate and hydrogen consumption than required by slurry hydrocracking processes. The LC-MAX process concept has been thoroughly vetted tlu·ough extensive pilot plant testing and is ready for conm1ercialization [ 4].

III. Conclusion Major upgrading processes such as Delayed Coking, Desulphurisation, LC Fining etc. not only upgrade the residue but also removes harmful contaminants. These teclmologies also allows Refineries to process larger quantities of heavy, high sulfur, low·er priced crndes, resulting in increased profitability. LC-FINING when combined with Delayed coking can handle very difficult (sourer, low quality) feed. Residue desulfurization process is relevant when there is a high premium for low sulphur fuel oil and there is high demand for gasoline.

References 1. Anm Arnra and Ujj al Mukhe1jee, "Refinery configuration for maximising middle di siillates", Chevron Lummus global. PTQ Q3 20


H. Khan er al., American Intenrntimrnl Journal of Research in Science. Tedmology. Engineering & Mathematics. 4(I), SeptemberNovember, 2013. pp. 71-73

2. A.nm Arora. Ujjal Mukhe1jee, "Refinery configuration for Maximum conversion to middle distillates". Annual meeting, March 20-22 ,201 l

3. Edward J. Houde, "W11en Solvent deasphalting is the most appropriate technology for upgrading residue", IDTC conference, London. England February 2006.

4. Mario Baldassari and Ujjal Mukhe1jee. "LC MA_X and Other LC FINING Process Enhancements to Extend Conversion and Onstream Factor". Annual Meeting March l 1-13. 2012

5. Mohan S. Rana a, Vicente sa ·m;no b, Jorge Anche)1a . J.A.I. Diaz, "A review of recent advances on process technologies for upgrading of heavy oils and residua, J.nstituto Mexicano del Petro Leo. Eje Central Lazaro Cardenas 152 , Mexico City D.F. , August 2006

6. A. Billon, F. Morel and J. P .. "Use of Solvent Deasphalting Process in Residues Conversion Schemes. 15th \Vorld Petroleum Congress, October l 2 - 17. 1997 . Beij ing, China.

7. Gmy Sieli and Nash Gupta , " Delayed Coking and LC-FINING Technology - A Winning Combination", 2008 ERTC Coking and Gasification conference, Rome. Italy

8. Sigrid Spieler, Ujjal Mukherjee. A:rt Dahlberg . "Upgradmg Residuum to Finished Products in Integrated Hydroprocessing Platfonns - Solutions and Challenges", 2006 NPRA, Utah


The Europetrole Article

- CBI Announces Refining Technology Award ... - Europetrole Page 1of2

News letter Votreemail Ok i Inscriptjgn I '=,!! ~ I @ .l:o.llt.il.ct Im Elilll ''*''

ACCUEIL NEWS EMPLOI ANNUAIRE D'ENTREPRISES RESSOURCES BLOG LE CLUB VOTRE COMPTE

accueil I actualite fran~aise I actualite internationale I recherche I interviews I focus I actualite de la sernaine I actualite petrole/gaz de schiste

Partager • [ll mt CJ CBI Announces Refining Technology Award in China

€dit€ le 08/04/2014 - Plus de news de "CB&I" - Vair la fi che entreprise de "CB&I"

CB&I announced its Chevron Lummus Global joint venture has been awarded a contract

valued in excess of $100 million. The scope of work includes the license, engineering

design package and cata lyst supply for three grassroots refinery units to be located in

China.

One unit will utilize LC-MAX residue hydrocracking technology - the first

commercialization for a grassroots unit. Another wil l util ize ISOCRACKING disti llate

hydrocracking technology, and t he third will uti lize VRDS vacuum residue desulfurization technology and UFR upflow

reactor technology, al l from Chevron Lummus Global.

"These cutting-edge hydroprocessing technologies will allow the customer to economica lly maximize the conversion of

a variety of heavy crude oil residues into high quali ty transport fue ls and other valuable products," said Daniel

McCarthy, President of CB&I 's Technology operating group.

About CBS.I

CB&I (NYSE; CBI) is the most complete energy infrastrncture focused company in the world and a major provider of

government services. With 125 years of experience and the expertise of approximately 55,000 employees, CB&l

provides reHable solutions while maintaining a relentless focus on safety and an uncompromising standard of quality.

Origine : Communique CB&I

Voir la fiche entreprise de "£Jliil"

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23/08/2014 - CBI Announces Technology Award in Poland

07/08/2014 - CBI Awarded Storage Tank Contract in Texas

08/07/2014 - CBI Awarded Sphere Storage Contract By Petrofac

02/07/2014 - CBI Awarded Contracts for Hydrocracker Complex in Russia

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18/03/2014 - CBI Announces LNG Award in Australia

11/12/2013 - CRT Awarded Contract fpr I NG I jm1efactj9n Termjnal

10/12/2013 - CBI Awarded FEED Contract for Hydrocracker Complex in Russia

22/11/2013 - CBI Awarded Storage Contract In Saudi Arabia

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- CBI Announces Refining Technology Award .. . - Europetrole

Ne~iPe¥:~~1 3 -~.,..~\lll;IH~r 1 gaffifFITD ~ 18@/2013 - CffLA---··---- r __ .. ___ .. ,,_i. I NG storage jn Asja

20/02/2013 - CR&! Anp911nre5 Off5hgre Award fur pmjert jn Nprwegjan Sea

26/12/2012 - CC 1y Awarded feed Contract for On5hnre Natural Ga5 I jg11efartjgn fadljtje5 jn the

Rep11b!js pf Mgzambjg11e

02/08/20 1 2 - CR&! Anp911nre5 Agreement tg Arq11jre the Shaw Grmm

30/07/2012 - Shaw Apn211nre5 Agreement tg Be Acm1jred by CB&!

22/05/201 2 - Shaw tg Sell Enemy & Cbemjspl5 Grn119 to Ierhpjp fur Anprnxjmately llSQ300 Mj"ign

20/03/2012 - Shaw Ann911nre5 G!qhal pq!ydyrene I jrep5jnq Alljanre wjth Iqta! petrnrhemjra's

16/02/2012 - freepnrt I NG fxgan5jnn I p and Zachry/CB&! lpjnt yenture Sjgn frnnt-fnd fngjneerjng

and pe5jpn Cqntract for Qeyelgpment pf freepgrt I jg11efartjpn prgjert near Freeport TeXi'5

10/01/20 12 - ShawCgr I td Ser11re5 Concrete Wejqht Cna1inn Contract fur a I atjn Amerjra Pine•ine

prgjert fpr Terhnin

13/12/2011 - Shaw tg Conduct Eesuijhjljty Study tg Rehabjljtate Refinery in I raq

22/07/2011 - CRT Awarded Asia ParjUr 1 NG Tank Contract

13/07/2011 - CRT Aw arded Contract fur II s Gas prnressinn e•ant

30/05/2011 - CR&! Awarded Ennineerinn Contract fgr Gplden Eagle Ofbhgre p!attgrms

22/04/2011 - Shaw awarded EEEQ rqntrnct in Abu Qhahi

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Page 2of2

.!fQ india Indonesia ~ ~ l.@!y ~ fil kazakhstan

~ licence !n.g !Y.!s.WJ. lundin malay5ia mer-du-nord

mozambique nabucco natura l-gas nigeria ~ nord-

~ ~ norway offshore .2!lli!..l.ill.Yfil!

~~~~~~ platform~~ refi nery ~!iQ.~ ~ ~ ~ sai pe m samsunq saudi-aramco

schlumberaer ~~~shell

~~~~sonatrach~

statoil storage subsea ~!i!JI. technip

.twW11 total llllW>:i. ll!.dlli!<..!.!!Lo !!.!<l<illlll= =..i

~m~~~

~ £.ll.lili.illi I GI~ I '" Partepajres I El Mentjgns !Pm1!es I .;h .PWJ.

1§15

Europetrole © 2003 - 20 15

http ://www.euro-petrole.com/cbi-announces-refining-tedmology-award-in-china-n-i-9406 12/21/2015

The PR Newswire Article

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CB&I Alm0tmces Refining Teclu1ology Award in Otina

mm ~.1 1

Far more 1nformation Vl!.il. www cb1 oom (h ttp /lwwi.w cb1 com) {PRNewsFoto/CB&I }

THE WOODLANDS, Texas, April 7, 2014 /PRNews'hire/ - CB&I (NYSE· CBI) today announced its Chevron Lummus Global joint

venture has been awarded a contract valued in excess of $100 million The scope of worl< includes the license, engineering design

package and catalyst supply for three grassroots refinery units to be located in China.

One unit will utilize LC-MAX residue hydrocracking technology - the first commercial ization for a grassroots unit Another will utilize

ISOCRACKING distillate hydrocracking technology, and the third wil l utilize VRDS vacuum residue desulfurization technology and UFR

upflow reactor technology, all from Chevron Lummus Global

'These cutting-edge hydroprocessing technologies will allow the customer to economically maximize the conversion of a variety of

heavy crude oil residues into high quality transporl fuels and other valuable products," said Darnel McCarthy, President of CB&l"s

Technology operating group.

About CB&!

CB&I (NYSE: CBI) is the most complete energy infrastructure focused company in the world and a major provider of government

services. With 125 years of experience and the expertise of approximately 55.000 employees. CB&t provides reliable solutions while maintaining a relentless focus on safety and an uncompromising standard of quality For more information visit .,.,.,,,,... cb1 com.

Important Information For Investors And Shareholders

Cautionary Statement Regarding Forward-Looking Statements

JomTt11llit~ and Bloggero

Visit PR Newswire for Journall sis, our

free resources for releases photos and

custorrized feeds. You can also send a

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Exhibit B

- CBI Announces Refining Technology Award ... - Europetrole Page 1of2

News letter Votreemail Ok i Inscriptjgn I 1¥3 ~ I @ .l:o.llt.il.ct Im Elilll •@HM

ACCUEIL NEWS EMPLOI ANNUAIRE D'ENTREPRISES RESSOURCES BLOG LE CLUB VOTRE COMPTE

accueil I actualite fran~aise I actualite internationale I recherche I interviews I focus I actualite de la sernaine I actualite petrole/gaz de schiste

Partager • [ll mt CJ CBI Announces Refining Technology Award in China

€dit€ le 08/04/2014 - Plus de news de "CB&I" - Vair la fi che entreprise de "CB&I"

CB&I announced its Chevron Lummus Global joint venture has been awarded a contract

valued in excess of $100 million. The scope of work includes the license, engineering

design package and cata lyst supply for three grassroots refinery units to be located in

China.

One unit will utilize LC-MAX residue hydrocracking technology - the first

commercialization for a grassroots unit. Another wil l utilize ISOCRACKING disti llate

hydrocracking technology, and the thi rd will utilize VRDS vacuum residue desulfurization technology and UFR upflow

reactor technology, al l from Chevron Lummus Global.

"These cutting-edge hydroprocessing technologies will allow the customer to economically maximize the conversion of

a variety of heavy crude oil residues into high quality transport fue ls and other valuable products," said Daniel

McCarthy, President of CB&I 's Technology operating group.

About CB&I

CB&I (NYSE; CBI) is the most complete energy infrastructure focused company in the world and a major provider of

government services. With 125 years of experience and the expertise of approximately 55,000 employees, CB&I

provides reHable solutions while maintaining a relentless focus on safety and an uncompromising standard of quality.

Origine : Communique CB&I

Voir la fiche entreprise de "£Jliil"

Retour

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18/12 - Snam S.p.A. Becomes Shareholder

in Trans Adriatic Pipeline CTAPl (lue 312

fois)

18/12 - Rosneft refineries complete

transition to Euro 5 motor fuels

production (lue 355 fois)

18/12 - Third Enemy grows onshore asset

base and become offshore operator (lue

196 fois)

18/12 - KCA Deutag 's Offshore and RDS

businesses awarded major contracts (1ue

237 fois)

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Gas Licensing Round Second Tranche

Offers ( Jue 261 fois)

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submitted (lue 264 fois)

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subsidia.-y sign agreement to build the

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Asia-China Gas Pipeline (lue 189 fois)

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to Avoid Production Interruptions (lue 187

fois)

18/12 - Aker Solutions and Saioem to Cooperate on Subsea Projects (lue 239 fois)

18/12 - Lake Charles LNG project receives

FERC approval (lue 178 fois)

>> Toute l 'actualitt! internationale >> ~

Recherche de news par tags

£l21?.~~gker-sol11tions~~

~™~ anqola ~™ austra lia

azerbailan barents-sea bechtel ~ ~ brazil

~~W~£llil.~1.b.i.o..d~

~ ~ commission-europeenne ~ ~

conocophil lips consommation ~ deepwater discovery

d rill i ng~~~~~ engineering

gill ~§i2~~~!!.ruL ~!!..Y.2r

f!.!d.m fmc foster-wheeler fQ§Q .fi!g.rQ ~ ~ ™

http: //www.euro-petrole.com/cbi-announces-refining-technology-award-in-china-n-i-9406 12/21 /2015

- CBI Announces Refining Technology Award ... - Europetrole

Ne~iPe¥:~~1 3 -~.,..~\lll;IH~r 1 gaffifFITD ~ 18@/2013 - CffLA---··---- r __ .. ___ .. ,,_i. I NG storage jn Asja

20/02/2013 - CR&! Anp911nre5 Off5hgre Award fur pmjert jn Nprwegjan Sea

26/12/2012 - CC 1y Awarded feed Contract for On5hnre Natural Ga5 I jg11efartjgn fadljtje5 jn the

Rep11b!js pf Mgzambjg11e

02/08/2012 - CR&! Anp911nre5 Agreement tg Arq11jre the Shaw Grmm

30/07/2012 - Shaw Apn211nre5 Agreement tg Be Acm1jred by CB&!

22/05/2012 - Shaw tg Sell Enemy & Cbemjspl5 Grn119 to Ierhpjp fur Anprnxjmately llSQ300 Mj"ign

20/03/2012 - Shaw Ann911nre5 G!qhal pq!ydyrene I jrep5jnq Alljanre wjth Iqta! petrnrhemjra's

16/02/2012 - freepnrt I NG fxgan5jnn I p and Zachry/CB&! lpjnt yenture Sjgn frnnt-fnd fngjneerjng

and pe5jpn Cqntract for Qeyelgpment pf freepgrt I jg11efartjpn prgjert near Freeport TeXi'5

10/01/2012 - ShawCgr I td Ser11re5 Concrete Wejqht Cna1inn Contract fur a I atjn Amerjra Pine•ine

prgjert fpr Terhnin

13/12/2011 - Shaw tg Conduct Eesuijhjljty Study tg Rehabjljtate Refinery in I raq

22/07/2011 - CRT Awarded Asia ParjUr 1 NG Tank Contract

13/07/2011 - CRT Aw arded Contract fur II s Gas prnressinn e•ant

30/05/2011 - CR&! Awarded Ennineerinn Contract fgr Gplden Eagle Ofbhgre p!attgrms

22/04/2011 - Shaw awarded EEEQ rqntrnct in Abu Qhahi

14/04/2011 - CR&! Announces Technglggy Award in Kazakhstan

22/03/2011 - CR&! Awarded Feed Contract for ya ma! I NG I jg11efactjon plant

16/03/2011 - ca&1 AnnP""Ges Kearl ni' sands contract

07/03/2011 - CH&I Awarded fEEQ Contract for Sphar Refinery in Oman

Page 2of2

.!fQ india Indonesia ~ ~ l.@!y ~ fil kazakhstan

~ licence !n.g !Y.!s.WJ. lundin malay5ia mer-du-nord

mozambique nabucco natura l-gas nigeria ~ nord-

~ ~ norway offshore .2!lli!..l.ill.Yfil!

~~~~~~ platform~~ refi nery ~!iQ.~ ~ ~ ~ sai pe m samsunq saudi-aramco

schlumberaer ~~~shell

~~~~sonatrach~

statoil storage subsea ~!i!JI. technip

.twW11 total llllW>:i. ll!.dlli!<..!.!!Lo!!.!< l<illlll= =..i

~m~~~

~ £.ll.lili.illi I GI~ I '" Partepajres I El Mentjgns !Pm1!es I .;h .PWJ.

1§15

Europetrole © 2003 - 2015

http ://www.euro-petrole.com/cbi-announces-refining-tedmology-award-in-china-n-i-9406 12/21/2015

ewswrre A UIM s* comp.art-,

r or Journa11sts >

For Bloggers > Global Sites "

I Search News Releases

Solutions Knowledge Center Blog 8ro'wse News Releases Contact PR NewS'N1re T Send 11 News Rele11se

See more news releases in Contracts

CB&I Alm0tmces Refining T eclu1ology Award in Otina

mm ~.1 1

Far more 1nformation Vl!.il. www cb1 oom (h ttp /lwwi.w cb1 com) {PRNewsFoto/CB&I }

THE WOODLANDS, Texas, April 7, 2014 /PRNews'hire/ - CB&I (NYSE· CBI) today announced its Chevron Lummus Global joint

venture has been awarded a contract valued in excess of $100 million The scope of worl< includes the license, engineering design

package and catalyst supply for three grassroots refinery units to be located in China.

One unit will utilize LC-MAX residue hydrocracking technology - the first commercialization for a grassroots unit Another will utilize

/SOCRACKING distillate hydrocracking technology, and the third will utilize VRDS vacuum residue desu/furization technology and UFR

upflow reactor technology, all from Chevron Lummus Global

'These cutting-edge hydroprocessing technologies will al low the customer to economically maximize the conversion of a variety of

heavy crude oil residues into high quality transporl fuels and other valuable products," said Darnel McCarthy, President of CB&/"s

Technology operating group.

About CB&/

CB&I (NYSE: CBI) is the most complete energy infrastructure focused company in the world and a major provider of government

services. With 125 years of experience and the expertise of approximately 55.000 employees. CB&t provides reliable solutions while maintaining a relent less focus on safety and an uncompromising standard of quality For more information visit .,.,.,,,,... cb1 com.

Important Information For Investors And Shareholders

Cautionary Statement Regarding Forward-Looking Statements

JomTt11llit~ and Bloggero

Visit PR Newswire for Journalists, our

free resources for releases photos and

custorrized feeds. You can also send a

free ProfNet request for experts.

Exhibit C


Engineering Design Package

LCMAX RESIDUE HVDROCRACKING PLANT Shandong Sincier Petrochemical Co. Ltd Dongying, P. R. China

Volume I - Process Design Information

September 2014

Chevron Lummus Global Bloomfield, New Jersey Richmond, California

CHEVRON LUMMUS GLOBAL BLOOMFIELD, NEW JERSEY

RICHMOND, CALIFORNIA

ENGINEERING DESIGN PACKAGE LCMAX RESIDUE HYDROCRACKING PLANT

UNIT 100

SHANDONG SINCIER PETROCHEMICAL CO. LTD DONGYING, P.R. CHINA

VOLUME I - PROCESS DESIGN INFORMATION

September 2014

Contributors: M. Baldassari P. Jaipersaud M. Razuk M. Cassidy T.Johnson M. Rickards B. J. Cooke S. Lee P. J. Risse M. DeAngelis J. Loganathan J. Ruby C. DeVito W.S. Louie P. Santos J. Ficarra U. Mukherjee J. Sauter J. Gonzalez M. Nardone R. Valente J. Grezzo S. Ohlmeyer C. Ilaria A. Olsen


SHANDONG SINCIER PETROCHEMICAL CO., LTD. DONGYING, P.R. CHINA


1.0 Introduction

I.I General 1.2 Scope of Work 1.3 Basis of Design

1.3. I Feedstock I. 3 .2 Products 1.3.3 Product Yields 1.3.4 Make-up Hydrogen 1.3.5 Injection Water 1.3 .6 Catalysts

Table of Contents

I. 3. 7 Reactor Operating Condi lions 1.3.8 Battery Limit Conditions 1.3.9 Start-up/Shut-down Fluids and Chemicals Requirements 1.3.10 Units of Measurement

Tables

I Feed Properties II Overall Product Yields III Product Properties IV Make-Up Hydrogen Composition V Amine Property Requirements VI Injection Water Specifications VII Catalyst Addition Rate VIII Reactor Operating Conditions IX Battery Limit Conditions - Incoming Streams X Battery Limit Conditions - Outgoing Streams XI Start-Up I Shut-Down Fluids and Chemical Requirements XII Units of Measurement

PFD - Piping and Equipment Symbology PFD - Instrument Symbology Sheet

Sincier LCMAX CONFIDENTIAL

PROPERTY OF CHEVRON LUMMUS GLOBAL TO BE REPRODUCED AND USED, ONLY IN

ACCORDANCE WITH WRITIEN PERMISSION OF CHEVRON LUMMUS GLOBAL

Drawing No.

BF-133101 BF-133102

June 2014




Table of Contents

2.0 Reaction Section

2.1 Process Description

2.1.1 Introduction 2.1.2 VR Feed Preheat Section 2.1.3 DAO Feed Preheat Section 2.1.4 VR Reaction Section 2.1.5 DAO Reaction Section 2.1.6 HP Purification and Hydrogen Recovery Section 2.1. 7 LP Separation and Flash Gas Recovery

2.2 Process Flow and Control Diagrams

Drawings PFD- Feed Section PFD - VR Reaction Section PFD - DAO Reaction Section PFD - Reactor Effluent Cooling PFD - H2 Recovery and Compression PFD - LP Amine Absorber PFD - Flash Gas Recovery PCD - Feed Section PCD - VR Reaction Section PCD - DAO Reaction Section PCD - Reactor Effluent Cooling PCD - H2 Recovery and Compression PCD - LP Amine Absorber PCD - Flash Gas Recovery

2.3 Stream Data

Component Summary Stream Data




Drawing No.

BF-133104 BF-133105 BF-133106 BF-133107 BF-133108 BF-133109 BF-133110 BF-133124 BF-133125 BF-133126 BF-133127 BF-133128 BF-133129 BF-133130

June 2014




Table of Contents

3.0 Fractionation Section

3. I Process Description

3.1.1 Introduction 3.1.2 Atmospheric Tower and Atmospheric Stripper 3.1.3 Sour Gas Compressor 3.1.4 Vacuum Tower and Vacuum Stripper


Drawings PFD-Atmospheric Tower PFD - Sour Gas Compression PFD-Atmospheric and Vacuum Stripper PFD - Vacuum Tower PFD - Vacuum Tower Overhead PCD - Atmospheric Tower PCD - Sour Gas Compression PCD - Atmospheric and Vacuum Stripper PCD - Vacuum Tower PCD - Vacuum Tower Overhead

3.3 Stream Data


4.0 Light Ends Recovery Section


4.1.1 Introduction 4.1.2 Light Ends Recovery section





Drawing No.

BF-133111 BF-133112 BF-133113 BF-133114 BF-133115 BF-133131 BF-133132 BF-133133 BF-133134 BF-133135

June 2014




Table of Contents

Drawings PFD - Light Ends Recovery Section PCD - Light Ends Recovery Section

4.3 Stream Data


5.0 Catalyst Handling Section

5. I Process Description 5.1.1 Basis of Design 5.1.2 Fresh Catalyst Handling 5.1.3 Daily Catalyst Addition/Withdrawal 5.1.4 Spent Catalyst Handling 5.1.5 Equilibrium Catalyst Withdrawal 5.1.6 Equilibrium Catalyst Addition (following turnaround)

5.2 Process Control Diagrams

Drawings PCD - Catalyst Handling Section PCD - Catalyst Handling Section PCD - Catalyst Handling Section

6.0 Process Control Strategy and Interlock Description

6.1 Design Philosophy 6.2 Continuous Control Philosophy: Reactor Temperature Surveillance System

6.2.1 Temperature Instrumentation 6.2.2 Application Philosophy 6.2.3 Temperature Surveillance Logic 6.2.4 Operator I Engineering Interface

6.3 Continuous Control Philosophy: Reactor Temperature Control 6.3.1 First LCMAX Reactor Temperature Control




Drawing No.

BF-133116 BF-133136

BF-133137 BF-133138 BF-133139

June 2014




Table of Contents

6.3.2 Second LCMAX Reactor Temperature Control 6.3.3 DAO LCMAX Reactor Temperature Control

6.4 Continuous Control Philosophy: Catalyst Bed Level Control Strategy

6.4.1 Normal Control 6.4.2 Faulty Detector Indication

6.5 Furnace Control 6.5.1 Firing Control

6.6 Continuous Control Philosophy: Reactor Automatic Cutback and Depressuring Application

6.6.1 Description 6.6.2 Malfunction Detection and Actions 6.6.3 Annunciation and Messages

6. 7 Emergency Shutdown System Philosophy 6.8 Interface with DCS

Appendix DCS System Requirements Specification

7.0 Safety, Health, and Environment

7.1 Safety

7.1.1 Safety Design Codes and Standards 7.1.2 Process Safety System Design Basis 7.1.3 Process Hazards and Safeguards 7.1.4 Fire and Explosion Hazards 7. I. 5 Chemicals Handling and Hazards

7.2 Health

7.3 Environment

CONFIDENTIAL Sincier LCMAX PROPERTY OF CHEVRON LUMMUS GLOBAL

TO BE REPRODUCED AND USED, ONLY IN ACCORDANCE WITH WRITIEN PERMISSION OF

CHEVRON LUMMUS GLOBAL

Drawing No.

June 2014




Table of Contents

7.3.1 Emissions 7.3.2 Effluent Summary 7.3.3 Effluents 7.3.4 Solid Wastes 7.3.5 Spent Catalyst Disposal 7.3.6 Environmental Information to Detailed Design Contractor 7.3.7 Environmental Information to Owner

Material Safetv Data Sheets IMSDS)

Catalyst Hydrogen Sulfide Nickel Carbonyl Methyldiethanolamine

8.0 Utility Summary

Utility Summary




Drawing No.

June 2014

1.0 - l

1.0 - INTRODUCTION

1.1 General

This package presents the Engineering Design Package (EDP) for a Chevron Lummus Global (CLG) licensed LCMAX RESIDUE HYDROCRACKING Plant for Shandong Sincier Petrochemical Co. to be constructed in Dongying, P.R China.

The capacity of the unit is 2.5 million MTA (46,158 BPSD) of vacuum residue.

The documents contained in the four volumes of this package comprise the EDP for the LCMAX Residue Hydrocracking Plant. This EDP reflects the extensive hydroprocessing experience of Chevron. Any deviations from this design should not be implemented without consulting CLG.

1.2 Scope of Work

The work performed is limited to the preparation of an EDP for the CLG licensed LCMAX Residue Hydrocracking Plant. The plant consists of a reaction section, fractionation section, light ends recovery section, and a catalyst handling section.

• Volume I presents the process information and drawings necessary to define the unit.

• Volume II contains detailed equipment specifications and drawings along with standard CLG specifications for equipment.

• Volume III contains piping and instrnmentation diagrams, materials recommendations and related engineering design information.

• Volume IV contains the instrnment data sheets and instrnment index.

CONFIDENTIAL PROPERTY OF CLG

TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE W ITH WRITIEN PERMISSION OF

1.0 - 2

1.3 Basis of Design

The basis of design is discussed in detail in this section.

1.3.l Feedstock

The LCMAX Residue Hydrocracking Plant is composed of a single train with two reaction stages. The overall vacuum residue feed rate to the Unit is 2.5 million MTA (46,158 BPSD). A breakdown of the feed can be found in Table I.

The on-stream time for the LCMAX Residue Hydrocracking Plant is 8150 hr/year with 50 days of turnaround during planned shutdown.

Both the high pressure reaction section and the low pressure fractionation section are designed for 50% turndown, unless otherwise stated.

1.3.2 Products

The following major products are produced from the unit:

• LPG

• Naphtha

• Diesel

• LLVGO

• VGO

• Vacuum residue



1.0 - 3

The by-products of this process include:

• Sweet fuel gas to fuel gas header • Non-condensables to OSBL amine absorber • Vacuum Tower slop oil to OSBL • Rich amine to amine regeneration unit (ARU) • Sour water to sour water stripping (SWS) unit • Blow-down from steam generators

The estimated product properties are shown in Table III.

1.3.3 Product Yields

The estimated product yields are shown in Table II.

1.3.4 Make-up Hydrogen

Hydrogen needed for the unit is supplied by the Make-up + Recycle Gas Compressor, the details of which can be found in the Reaction Section, Section 2.0. The source of the hydrogen to the make-up section is an off-plot Gasifier/ PSA. The properties of the make-up hydrogen are shown in Table IV.

1.3.5 Injection Water

A combination of stripped sour water and water from the Atmospheric Tow er overhead system is used to supply injection water to the LCMAX Residue Hydrocracking Plant. If this water is insufficient to meet total demand, a make-up water stream of boiler feed water is routed to the unit. The injection water must meet the inspections in Table VI.

1.3 .6 Catalysts

The catalyst addition rates and the estimated initial inventories for the LCMAX Residue Hydrocracking Plant are tabulated in Table VII. The catalyst addition rates reported in this table were determined based on:

• Kinetic rate constants ( desulfurization, demetallation, CCR and asphaltenes reduction) derived from pilot plant data as well as actual commercial operating data.

• A single back mixed reactor for the DAO.

• A two-back-mix reactor in series model for the virgin feed.

• Statistical catalyst age distribution functions for each reactor.



1.0 - 4

• Parallel addition of fresh to the each of the three reactors plus countercurrent cascading of catalyst from the DAO reactor to the Second LCMAX reactor. The fully spent catalyst is discharged from the First and Second LCMAX reactors.

The countercurrent mode of addition results in higher overall reaction rate constants and therefore better overall catalyst utilization based on the concentration of metals on the spent catalyst. Catalyst cascading also has the added benefit of exposing the most highly converted material to the most active catalyst.

1.3. 7 Reactor Operating Conditions

Reactor operating conditions can be found in Table VIII.

1.3 .8 Battery Limit Conditions

The battery limit conditions for the incoming and outgoing streams are shown in Tables IX and x.

1.3.9 Start-up I Shut-down Fluids and Chemicals Reguirement

Start-up I shut-down fluids and chemicals requirements are included in Table XI.

1.3.10 Units of Measurement

The units of measurement used for the project are shown in Table XII.



1.0 - 5

Table I -Feed Properties

Property

Crude Source

Feed Rate, tph

Density (q) 20 °c g/cm5

Viscosity (100°C), nun"/s

Solidifying Point °C

CCR, wt%

Sulfur, wt%

Nitrogen, µg/g

Hydrogen,%

Metals, µg/g Ni v Fe Na

SARA, wt% Saturates Aromatics Gelatine (Resins) Asphaltenes(C7 Insoluble)

TBP Distillation, 0c IBP 10 vol% 15 vol%

Vacuum Residue

Merey I Middle East Blend

306.9

1.0037

1946

42

25.0

4.31

3700

10.62

101 206 60 40

20.84 28.64 35.5 15.02

480 550

557.3


TO BE REPRODUCED, AND USED; ONLY IN ACCORDANCE WITH W RITTE N PERMISS ION OF


Feed Wt% Vol% 360-550°C 14.14 15.00 550 1°C 85.86 85.00 Total 100.00 100.00

Products Wt% Vol% H2S 3.75 NH3 0.22 H20 0.33 C1 1.36 C2 1.18 C3 1.42 C4 1.38 2.38 Cs- l 65°C 10.65 14.70 l 65-360°C 37.63 44.27 360-550°C 35.30 37.88 Asphalt 8.79 7.59 Total 102.00 106.81

Liquid Products Wt% Vol% c/ 93.75 106.81 C4-550C 84.96 99.23 Cs-550C 83.58 96.85 Cs+ 92.37 I 04.44

1.0 - 6

Table II - Overall Product Yields - 90% Conversion (550°C+)

API 18.00 8.07 9.47

API

63.00 34.38 19.77 -9.74

API 29.12 33.14 31.86 27.90

SG 0.9465 1.0138 1.0037

SG

0.5840 0.7275 0.8530 0.9354 1.1621

SG 0.8809 0.8594 0.8662 0.8877

Swt% Nwt% 2.10 0.20 4.67 0.40 4.31 0.37

Swt% Nwt% 94.08

82.24

0.056 0.018 0.271 0.075 0.868 0.226 3.475 1.006

Swt% Nwt% 0.768 0.211 0.488 0.129 0.496 0.131 0.779 0.215


TO BE REPRODUCED. AND USED ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF


Owt% Vwnnm 0.10 0.50 240 0.44 206

Owt% Vwppm

88.81

0.035 0.072 0.144 1 0.768 312

Owt% Vwppm 0.159 0.096 0.098 0.161

Ni wnnm CCR wt% 0 1.0

118 29.0 101 25.0

Ni wppm CCR wt%

0.5 0.5 317 69.0

Ni wppm CCR wt%

1.0- 7

Table II Continued - Overall Product Yields - 90% Conversion (550°C+)

Chemical H2 Consumption, Nm3/m3

Impurities Removal Sulfur Nitrogen CCR Vanadium Nickel


TO BE REPRODUCED AND USED, ONLY IN ACCORDANCE WITH WRITIEN PERMISSION OF


222

Wt% 83.3 46.5 75.0 86.5 72.2

1.0- 8

Table III - Product Properties

Fuel Gas

H2S, vppm < 50

Water, vol% 1.4

Hydrogen, vol% 38.6

Methane/ Ethane, vol% 33.6 I 13.8

Propane, vol% 8.4

Butane, vol% 2.3

cs+, vol% 1.9

LPG

Specific Gravity 0.509

Copper Strip Corrosion < l *

Mercaptau Sulfur, wppm < l *

Total Sulfur, wppm < l *

C2, vol% < 0.05

C3, vol% 28.6

C4, vol% 70.4

Cs+, vol% 1.6

Residue ou Evaporation, mL/lOOmL < 0.05

Free Water Nil

*After amine and caustic treatment. Common treatment with hydrocracker LPG product provided within the hydrocracker battery limits.


TO BE REPRODUCED AND USED ONLY IN ACCORDANCE WITH WRITIEN PERMISSION OF


1.0- 9

Table III Continued - Product Properties Table

Naphtha (Cs-165°C)

Specific Gravity

Total Sulfur, wppm

Total Nitrogen, wppm

Paraffins, vol%

Olefins, vol%

Naphthene, vol%

Aromatics, vol%

Bromine Number

D86 Distillation, °C

ILV%

5LV%

IOLV%

30LV%

50LV%

70LV%

90LV%

95LV%

98LV%




0.7275

560

180

56

2

31

II

5

39

71

85

105

121

132

145

156

173

1.0- 10

Table III Continued - Product Properties

Diesel (165°C-360°C)

Specific Gravity

Total Sulfur, wppm

Total Nitrogen, wppm

Total Aromatics, vol%

Di I Tri-Aromatics, vol%

Polycyclic Aromatics, vol%

Flash Point, °C

Cetane Index, D4737

Stability Test, mg/lOOml(D-2274)

Cloud Point, °C

Pour Point, °C

D86 Distillation, °C

lLVo/o

5LV%

lOLVo/o

30LV%

50LV%

70LV%

90LV%

95LV%

98LV%




0.8530

2710

750

40.0

6.5 I l.5

2.0

> 48

45.5

< 25.0

-16.0

-19.0

180

194

203

238

258

292

325

339

373

1.0 - 11


VGO (360-550°C)

Specific Gravity

Total Sulfur, wt%

Total Nitrogen, wt%

Nickel Content, wppm

Vanadium Content, wppm

Total Metal, wppm

Conradson Carbon, wt%

Viscosity (m 100°C cSt

Asphaltene Content, wt%

WatsonK

Boiling Range (TBP), °C

1LV%

5LV%

10LV%

30LV%

50LV%

70LV%

90LV%

95LV%

98LV%




0.9354

0.868

0.226

< 1.0

1.0

< 3.0

0.5

8.6

< 1.0

11.58

334

360

371

412

434

457

488

500

533

1.0 - 12


Vac Tower Btms (VTB)

Specific Gravity 1.0235

Total Sulfur, wt% 2.13

Total Nitrogen, wt% 0.45

Ni Content, wppm 74

Fe Content, wppm < 30

V Content, wppm 72

Na, wppm < 20

Total Metal, wppm (Note 2) < 200

Conradson Carbon, wt% 29.0

Viscosity (lil 100°C cSt 2200

Asphaltene Content, wt% 20.0

Boiling Range (TBP), °C

1LV% 482

5LV% 515

10LV% 535

30LV% 614

50LV% 682

70LV% 747

90LV% 854

95 LV% 881

98LV% 897

(1) *Properties for the LCMAX Vacuum Tower Btms Product (SDA Feed) which includes· 15% VGO range material.

(2) Excluding LC-Fining catalyst fines which are approximately 100 wppm




1.0 - 13

Table IV - Make-Up Hydrogen Composition

Site Property Typical Condition

Hydrogen, Mole %, Min. 99.0 99.9

Methane, Mole %, Max. 0.9 0.1

N1, Mole ppm, Max. 1,000 <l,000

CO + C02, Mole ppm, Max. <10 <20

Chloride, Mole ppm, Max. 1 Nil

Source H2 Plant Gasifier/PSA

Table V - Amine Properties Requirements

Amine Properties Typical

Amine Selection (e.g., DEA, MDEA)

Amine Concentration, Wt%

Lean Amine Loading, Mol H2S/Mol Amine

Rich Amine Loading, Mol H2S/Mol Amine




Site Condition

MDEA

40.0

0.01

0.4

1.0 - 14

Table VI - Injection Water Specifications

Property Maximum Preferred

H2S, Wt ppm 1000 <50

Ammonia, Wt ppm 1000 <50

Oxygen, Wt ppb 15 <10

pH 8-10

Iron, Wt ppm 1 <0.2

Chlorides, Wt ppm 50 <10

Calcium, Wt ppm 3

Cyanide Nil

Phenol Nil

Particulates> 25 microns (wt.%) 1

Total Disolved Solids (TDS) 250




Site Condition

<50

<50

<10

8-10

<0.2

<10

Nil

Nil

<l

<250

1.0 - 15

Table VII - Catalyst Addition Rate

ICR-622 ICR-630 Catalyst Addition Rate

Nonnal (kg/MT) 0.57 0.47 Design (kg/MT) 0.74 0.61

Catalyst Consumption, Nomrnl (kg/dav) 4200 3460 Design (kg/day) 5460 4500

Cycle (hours) I Batch 10 to 13

Catalyst Batch Nomrnl (kg) 5600 4615 Design (kg) 7280 6000

Catalyst Density Fresh (kg/m3

) 497 545

100-R-101 100-R-102 & 103 Catalyst Inventory in Reactor

Reactor Size, Dia x T-T (mm) 4,013 x 35,966 ( 3 reactors) Catalyst Volume (m 3)/ reactor 290 I 290 Catalyst Weight (kg)/ reactor 144130 I 158050

Frequency of Fresh Catalyst Addition 3 batches (total) per 48 hours




1.0 - 16

Table VIII - Reactor Operating Conditions

lstLCMAX 2n"LCMAX Operating Conditions Reactor Reactor

(100-R-101) (100-R-102) Operating Pressure, MPa (g) Reactor In 18.00 17.23 Reactor Out 17.61 16.84 Operating Temperature, °C Reactor In 374 402 Reactor Out 430 435

Design Pressure, MPa (g) 20.20

Design Temperature, °C 468

Reactor Dimensions ID, mm 4,013 Tangent-Tangent Height, mm 35,966

Reactor Metallurgy Base Material


2 Y4 Cr-1Mo-Y4V

TO BE REPRODUCED; AND USED, ONLY IN ACCORDANCE W ITH WRITTEN PERMISSION OF


DAOLCMAX Reactor

(100-R-103)

17.23 16.84

373 443

Incoming Stream Phase

YR Feed Cold L

YR Feed Hot L

SR Diesel Feed 2 L

SR VGO Feed 3 L

DAO L

Make-up H2 v

Stripped Sour Water L

(Injection Water)

Lean Amine L

Utilities

Superheated High v Pressure Steam

Superheated Low v Pressure Steam

Boiler Feedwater L

Cooling Water Supply L

Nitrogen v Fuel Gas v

1.0 - 17

Table IX-Battery Limit Conditions - Incoming Streams

Source

VDU

Storage

CDU

VDU

SDA

sws

ARU

Steam Header

Steam Header

To

YR Feed Surge Drum

YR Feed Surge Drum

DAO Feed Surge Drum

(startup and emergency)

DAO Feed Surge Drum

(startup and emergency)

DAO Feed Surge Drum

Reactor/Make-up H2

Sections

Injection Water Drum

Lean Amine Surge Drum

Steam Generators

Water Coolers

Surge Drums

Furnaces




Pressure (MPa(g))

1.0

1.0

1.0

1.0

1.0

2.0

0.6

0.6

3.3-3.5

0.8-1.2

5.0

0.4-0.45

0.6-0.8

0.5

Temperature (0 C)

110

170

50

70

150

40

50

50

390

230-290

100-105

32

40

40

Outgoing Stream Phase

Sweet Fuel Gas v LPG L

Naphtha L

Diesel L

LLVGO L

VGO L

SDA Feed (VTB) L

Non-Condensables v Slop Oil L

Sour Water L

Rich Amine L

Cooling Water Return L

1.0 - 18

Table X-Battery Limit Conditions - Outgoing Streams

Source To

Flash Gas Amine Absorber Offplot Fuel Gas System

Naphtha Stablizer LPG Treatment (HCR)

Naphtha Stabilizer Storage

Atm. Tower Storage

Vacuum Tower Storage

Vacuum Tower Storage

Vacuum Tower SDA

Vacuum Tower Ovhd Offplot

Vacuum Tower Ovhd Offplot

Sour Water Degasser Offplot SWS

Rich Amine Flash Drum Offplot ARU

Water Coolers Offplot Cooling Tower




Pressure (MPa(g))

0.5

2.69

0.5

0.5

0.5

0.5

0.5

0.0

0.6

0.5

0.65

0.2 - 0.25

Temperature (0 C)

50

42

40

45

45

90

238

55

42

54

67

40 - 42

1.0 - 19

Table XI - Start-Up I Shut-Down Fluids and Chemical Requirements

This part will be further confinned in the Process Manual.

Start-up/Shutdown Fluids Property Site Condition

SR Diesel BPSD > 30kBPSD

Sulfur, wt% 1.0 ... 1.5

SRVGO BPSD > 40kBPSD

Sulfur, wt% 2.5

Dielectric strength

Viscosity, cp 8.0

Notes:

1. CLG recommends using straight nm diesel and straight nm VGO as flushing oil.

2. Additionally, a light VGO fraction with less than 0.5 wt% sulfur is requires for seal oil for the ebullating pumps; as an example hydrocracker unconverted oil.




1.0- 20

Table XII - Units of Measurement

Measurement

Temperature

Pressure

Pressure, Operating

Vacuum

Weight (Mass)

Density- Liquid, Vapor

Enthalpy

Enthalpy, Total

Flow Standard - Liquid

Flow Standard - Gas

Flow Condition - Liquid

Flow Condition - Gas

Flow- Liquid, Vapor

Viscosity

Thennal Conductivity

Specific Heat

Power

Heat Transfer Coefficient

Dimensions

Pipe Diameter

Tubing Size

Velocity

English

Of

psi

ps1g

mmHg

Lb

Lb/Ft3

Btu/Lb

MMBtu/Hr

BPOD (al 60°F

MMSCFD @ 60°F & I ATM

GPM

MCFH

Lb/Hr

cP

Btu/Hr/Ft/°F

Btu/Lb/°F

Btu/Hr, hp

Btu/Hr-Ft2 - °F

Ft, In.

Ill.

Ill.

Ft/s




Client Units

oc

MP a

MP a ( g)

mmHg

Kg

kg/m3

kJ/kg

MW

m3/h (illl5.6 °C

Nm3/h (al 0°C & I ATM

m3/h

m3/h

kg/h

cP

W/ Cm. 0 c l

kJ/kg/°C

kW

W(m2oq

Mm

Ill.

Mm

mis

CIXllXI) CID=D

!j! ~ ' ~ ~ i !

~D ~ ~ -

' ' r p

il c::JI

c:::J

) ~ ~~-(

B~ ~~

Q~ ~2 ~~

~L__~_____:_ir -----=-:1 ~~r-1 r

~ @] dD , '

511 ~

I ' 11 ' ' ' ' LJ l

' ij

'

I ~ ~ = ! ~ ~~ ' ~ z ' ~~ " c ~,

" l e z

"

J I I 1 I '~ j ., I I f ' ' ' ' i ~ ' !

~ i ' ~ 2 ~ ~ ~ ~ ~

'

1':31 ~ ~ h

~~ ~

ii I i

'

II

CD

11

El li t'.Bj l!!

i! 3 ~!

2.0 - 1

2.0 - REACTION SECTION


2.1.1 Introduction

The following is a description of the reaction section scheme as depicted on the Process Flow Diagrams BF-133104 through BF-133110. The reaction section consists of two reaction stages. The first stage consists of two VR LCMAX reactors in series with an inter-stage separator. The unconverted vacuum residue from the bottom of the Vacuum Tower is routed to a Solvent Deasphalting Unit (SDA). The deasphalted oil (DAO) is then processed in a dedicated second stage reactor, which operates in parallel to, and at the same pressure as the first reaction stage. The second stage consists of one DAO LCMAX reactor. The products from the first stage and second stages are combined and processed in the same Atmospheric Fractionation, Vacuum Fractionation, and Light Ends Recove1y sections. The Catalyst Handling system is common to both reaction stages.

The three reactors, two LCMAX reactors and single DAO LCMAX reactor, are designed for an overall 90% conversion of the 550°C+ material in the feed to 550°C material. This description subdivides the reaction section into 8 parts: VR feed preheat section, DAO feed preheat section, VR reaction section, DAO reaction section, HP purification and hydrogen recove1y system, LP separation and flash gas recovery.

2.1.2 VR Feed Preheat Section

Hot vacuum residue and cold vacuum residue (VR) feed (via a pressure controller) are received from OSBL and are preheated in the vacuum fractionation section by heat exchange with the LVGO and HVGO pumparounds and Vacuum Tower bottoms product in exchangers 100-E-405, 100-E-406, and 100-E-407 respectively. The preheated feed oil is then sent to the VR Feed Surge Drum (100-V- l 01) along with preheated DAO from the offplot SDA. The VR feed is raised to the reaction loop pressure by the VR Feed Pumps (100-P-103A/B) and further preheated against HP/HT vapor in the Feed Oil Preheat Exchanger (100-E-103). Hot recycle gas is mixed with the VR feed upstream of 100-E-103. A small portion of the VR feed from 100-P-103A/B is routed directly to the Interstage Separator (100-V-1 03) as quench without any additional heating. The feed from 100-E-103 is sent to the Reactor Feed Furnace (100-H-101), where it is heated to reaction temperature.

The Reactor Feed Furnace shutdown interlock is activated by 2 out of 3 low low signals from total oil flow. Other triggers include high high outlet temperature, low foel/pilot gas pressure, emergency depressuring and others by DDC/furnace vendor.

2.1.3 DAO Feed Preheat Section

DAO from the off plot SDA is preheated against Vacuum Tower bottoms in the Vacuum Tower Bottoms/DAO Feed Exchanger (100-E-408). This preheated DAO splits to feed both the VR and


TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE VVITH WRITTEN PERMISSION OF


2.0 - 2

DAO Reaction Section. The preheated DAO feed to the DAO Reaction Section is mixed with Vacuum Stripper bottoms recycle from the Vacuum Stripper Bottoms Pump (100-P-401A/B) and the HVGO cut from the Vacuum Tower and sent to the DAO Feed Surge Drum (100-V-102).

The DAO Reactor feed is raised to the reaction loop pressure by the DAO Feed Pumps (100-P-104A/B) mixed with hot recycle gas and sent to the DAO Feed Furnace (100-H-102), where it is heated to reaction temperature.

2.1.4 VR Reaction Section

Preheated fresh VR feed is accumulated in the VR Feed Surge Drnm and is pumped to the reactors through the Feed Oil Preheat Exchanger and Reactor Feed Furnace. The outlet temperature from the Reactor Feed Furnace is adjusted to control the 1st LCMAX Reactor (100-R- l 01) inlet temperature. The furnace firing is controlled to insure that the mixed feed temperature satisfies the reactor heat balance and maintains the average reactor temperature. The difference between the reactor average temperature and the mixed phase inlet temperature is a function of the net heat generated from the exothermic hydrogenation and endothermic cracking reactions occurring within the reactor. A small portion of the feed oil from the VR Feed Pumps is diverted from upstream of the Feed Oil Preheat Exchanger and used for quenching the effluent from the 1st LCMAX Reactor.

The hot, mixed feed and gas enters the bottom head of the l st LCMAX Reactor through a ring type distributor and mixes with the recirculating oil from the 1st LCMAX Reactor Recycle Pump (100-P-101). This gas/liquid mixture is then distributed via the primary vapor/liquid distributor into the bottom of the expanded bed.

In the LCMAX reactors , the feed is reacted catalytically in the presence of hydrogen. In an expanded bed reactor, the catalyst particles are kept in random motion by internal recirculation of the reactor liquid via the LCMAX reactor recycle pumps. The recycle pump speed is adjusted to keep the catalyst suspended to the proper level in the reactor as determined by the nuclear density detectors. Catalyst is withdrawn from each reactor daily and replaced with fresh catalyst (refer to the Catalyst Handling System description in Section 5.0).

The vapor/liquid effluent from the top of the 1st LCMAX Reactor is quenched with liquid quench oil and VR feed and flashed in the Interstage Separator (100-V- l 03). The liquid from l 00-V- l 03 is mixed with recycle gas and sent to the 2nd LCMAX Reactor (100-R-102) for further residual convers10n.

During normal operation, the 211d LCMAX Reactor inlet temperature controller controls the flow

of wmm and hot hydrogen to satisfy the heat balance. In case that the inlet temperature is too high and the warm hydrogen flow reaches a certain preset limit, the inlet temperature controller opens the quench oil flow controller to reduce the inlet temperature. Once the flow of wmm hydrogen gas has dropped, the controller switches back to controlling the hot and cold gas.




2.0 - 3

The recycle pump in each LCMAX reactor draws suction from a recycle pan located in the top portion of the reactor, above the expanded catalyst bed. The catalyst-free oil which overflows into the pan, flows through a downcomer pipe to the recycle pump, the impeller and diffuser of which are located inside the bottom head of the reactor. The internally recirculated liquid mixes with the oil and vapor stream entering the reactor, and flows up into the expanded bed through the primmy vapor/liquid distributor. The bed level is controlled by adjusting the speed of the reactor recycle pump. As a result of the back-mixing induced within the expanded bed by the recirculation of reactor liquid, very low temperature gradients are experienced.

The mixed phase reactor effluent is combined with the vapor from the Interstage Separator and quenched with quench oil and cold recycle gas before being separated in the VR HP/HT Separator (100-V-104). The vapor from the VR HP/HT Separator is combined with the DAO HP/HT vapor and used to heat other process streams. The liquid from 100-V-l 04 is let down in pressure and further separated in the VR MP/HT Separator ( 100-V-l 05). The vapor from 1 OO-V-105 is combined with the DAO MP/HT vapor and used to heat the Atmospheric Tower feed. The liquid from 100-V-105 is sent to the Atmospheric Tower (100-T-301).

2.1.5 DAO Reaction Section

After final heating in the DAO Feed Furnace, the hot feed oil mixes with a hot, hydrogen-rich gas stream. The outlet temperature fi:om the DAO Feed Furnace is adjusted to control the DAO LCMAX Reactor (100-R-103) inlet temperature. The furnace firing is controlled to insure that the mixed feed temperature satisfies the reactor heat balance and maintains the average reactor temperature. The difference between the reactor average temperature and the mixed phase inlet temperature is a function of the net heat generated from the exothermic hydrogenation and endothermic cracking reactions occurring within the reactor.

The hot, mixed DAO feed and gas enters the bottom head of the DAO LCMAX Reactor through a ring type distributor and mixes with the recirculating oil from the DAO LCMAX Recycle Pump (l 00-P-l l 0). This gas/liquid mixture is then distributed via the primary vapor/liquid distributor into the bottom of the expanded bed.

In the DAO LCMAX Reactor, the feed is reacted catalytically in the presence of hydrogen in the same manner as the other LCMAX reactors. The control of the DAO LCMAX reactor is identical to the 1st LCMAX reactor described above.

The mixed phase reactor effluent is quenched with quench oil and cold recycle gas before being separated in the DAO HP/HT Separator (100-V-106). The vapor from 100-V-106 is combined with its counterpart HP/HT vapor from the first stage, and used to heat other process streams. The liquid from 100-V- l 06 is let down in pressure and further separated in the DAO MP/HT Separator ( 100-V-107). The vapor from 100-V- l 07 is combined with its counterpart vapor from the first stage and used to heat the Atmospheric Tower feed. The liquid from 100-V- l 07 is sent to the Atmospheric Stripper ( 1 OO-T-303).




2.0 - 4

2.1.6 HP Purification and Hydrogen Recoverv Section

The reactor effluent vapor from the two HP/HT Separators is cooled by preheating recycle hydrogen gas (in two services), VR feed oil, and generating HP steam prior to entering the HP/MT Separator (100-V-l 08). The temperature in l 00-V-l 08 is adjusted controlling the pressure of the generated steam. The liquid from l OO-V-108 is letdown on level control to the MP/MT Separator (l 00-V- l l 0) for recove1y of flash gas .

The vapor from l 00-V- l 08 is then mixed with wash water, to prevent the prec1p1tation of ammonium salts, as it is further cooled to 50 °C in the HP/MT Flash Gas Cooler (100-A-101) . The quantity of wash water is flow controlled and is adjusted to limit the concentration of ammonium salts in the effluent water and maintain sufficient liquid water in the inlet of l OO-A-101. The three-phase mixture leaving the air cooler enters the HP/LT Separator (100-V-109), where the vapor, liquid hydrocarbon, and water phases are separated. The recovered sour water is sent to the Sour Water Degasser (100-V-121) before going out to battery limits. TI1e vapor stream from 100-V-109 is sent to the HP Amine Absorber & Wash Column (100-T-101) via the HP Centrifugal Separator (100-V-l 12). In 100-T-101 , the process vapor is contacted with lean amine to remove H2S, and then scrubbed with wash water to minimize any amine or ammonia entrainment. A 6°C temperature difference is maintained between the lean amine and sour gas to avoid condensation of hydrocarbons in the amine absorber. The recovered liquid hydrocarbon from l 00-V- l 09 is letdown on interface level control, mixed with MP/LT oil, and routed to the LT Oil Flash Drnm (l OO-V-123) where it is separated into sour gas, Atmospheric Tower feed, and sour water streams.

The product gas leaving the HP Amine Absorber & Wash Column is sent to the Membrane K.O. Drum (100-V-l 13) and heated with LP steam in the Membrane Feed Heater (100-E-l 10), before entering the Membrane Unit (100-ME-101), a two-stage membrane unit package, where light hydrocarbon gases, C1 - C4, formed in the hydrocracking reactors are removed, so as to maintain the hydrogen purity of the treat gas to the reactors . The steam heater is required to heat the gas to 90 °C to meet the superheat requirement for the membrane unit. A portion of the feed gas is bypassed around the membrane unit for pressure control. The first stage permeate mixes with 100-C- l 0 l second stage compressed recycle gas, while the second stage permeate cooled by the 211

d Stage Permeate Cooler ( l 00-E-l l 5) mixes with the off gas from l OO-V-125 and routed to the PSA Unit (100-ME-107). The high purity hydrogen from the PSA is combined with make-up hydrogen from OSBL for compression by the MU + RG Compressor (100-C-lOlA/B/C) and the tail gas is mixed with sour gas from the Atmospheric Tower for compression by the Sour Gas Compressor ( l OO-C-30 lA/B).

The combined gas stream is compressed to the required reaction loop pressure in the third stage of l 00-C-l 0 lA/B/C. Two compressors are operated in parallel with a spare machine to supply the treat gas required. There is a spillback control on the third stage discharge of the compressor




2.0 - 5

which operates on differential pressure control to make sure hydrogen pressure is adequate to feed into the reactors . There is also a pressure controlled spillback downstream of the second stage discharge.

2.1. 7 LP Separation and Flash Gas Recove1y

Liquid from the VR MP/HT Separator is fed directly to the Atmospheric Tower on level control while the flashed vapor from the VR and DAO MP/HT Separators is cooled by preheating Atmospheric Tower Feed in 100-E- l 12 A/Band then mixed with HP/MT oil prior to generating LP steam in the MP/HT Vapor/LP Steam Generator (100-E-l 13). A spare shell is provided for 1 OO-E- l l 2A/B due to the fouling nature of this service. The vapor/liquid mixture from 1 OO-E-113 is then flashed in the MP/MT Separator ( 1OO-V-110), with a portion of the liquid going to the Atmospheric Tower and the remainder used as quench for the reaction section.

Vapor from the MP/MT Separator is mixed with wash water, to prevent the precipitation of ammonium salts, as it is further cooled by cooling water in the MP/MT Vapor Cooler (100-El 14). The quantity of wash water is flow controlled and is adjusted to limit the concentration of ammonium salts in the effluent water and maintain sufficient liquid water in the cooler feed. The three-phase mixture leaving the water cooler enters the MP/LT Separator (1 OO-V-111 ), where the vapor, liquid hydrocarbon, and water phases are separated. The recovered sour water is sent to the Sour Water Degasser (100-V-1 21) on level control to remove any gas before going to battery limits . The hydrocarbon liquid from the MP/LT Separator is let down on level control and fed to 100-V-123. The vapor stream is sent to the LP Amine Absorber (100-T-102) via LP Centrifugal Separator (100-V-1 24) where it is scrubbed with lean amine to remove H1S in order to achieve a suitable H2 purity to combine with the make-up hydrogen. The scrubbed offgas is then fed to the Offgas K.O. Drum (100-V-125), where any entrained amine is removed, and then sent on pressure control to 100-ME-107.

The hydrocarbon liquid from the MP/LT separator is let down on level to flow control, mixed with HP/LT oil and flashed in the LT Oil Flash Dnnn (1 OO-V-123) and then preheated by Atmospheric Tower pumparound, diesel product, and MP/HT vapor in the LT/MT Oil/Atm Tower PA Exchanger (100-E-302), LT Oil/Diesel Exchanger (100-E-301A/B), and MP/HT Vapor/ Attn Tow er Feed Exchanger (1 OO-E-112 A/B) respectively before entering the LT /MT Oil Surge Drum (100-V-301). The feed to 100-V-301 is temperature controlled by bypassing MP/HT vapor around 100-E-l 12A/B.

The process wash water consists of stripped water from OSBL, Atmospheric Tower water pumped from the Atmospheric Tower Reflux Drnm (100-V-302) and Atmospheric Tower Overhead Product Dnnn (100-V-303), and, if necessmy, supplemented by BFW. The stripped water is fed on level control to the Injection Water Drum (1 OO-V-119) after mixing with the other water sources. The process wash water injected upstream of the HP/MT Flash Gas Cooler and as wash water in the HP Amine Absorber & Wash Column is supplied by the HP Wash Water pumps (100-P-106A/B). The injection water to the MP/MT Vapor Cooler is supplied by the MP Wash Water Pumps (100-P-109A/B). Both 100-P-106A/B and 100-P-109A/B take suction from the Ii~iection Water Drum.




2.0 - 6

The lean amine from OSBL is fed to the Lean Amine Surge Drum ( 1 OO-V-120) on level control. The HP Lean Amine Pumps (100-P-107 A/B) supply lean amine to the HP Amine Absorber, while the LP Lean Amine pumps (100-P-108A/B) supply lean amine to LP Amine Absorber and Flash Gas Amine Absorber.






TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF


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0 0

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2.3 Stream Data

This section contains the reaction section stream data and component balances for normal operating conditions. Included are component balance sheets showing detailed component breakdown and stream data sheets showing flow rates and physical properties for each stream.




Stream No From To Content

START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'ihr @1 Total Vap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq . Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY

REACTION AND SEPARATION

LCMAX RESIDUE HYDROCRACKING PLANT SHANDONG SINCIER PETROCHEMICAL CO ., LTD.

DONGYING, P.R. CHINA

101 102 103 104 OSBL 100-E-405 100-E-406 100-E-407

1 OO-E-405 100-E-406 100-E-407 MIX FEED OIL FEED OIL FEED OIL FEED OIL

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

306899 306899 306899 306899 0 0 0 0 0 0 0 0

306899 306899 306899 306899 395 395 395 395

306.4 306.4 306.4 306.4

MAT BAL REFLECTS A 0. 1% CONVERGENCE OF THE PROCESS MODEL.

Confidential Property of Chevron Lummus Global LLC

I Eng: IAprvd:

I Page

105 VALVE

100-V-101 FEED OIL

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

306899 32610

0 339509

439 339.1

I Date: 06/13/2014

1 of 301

110 100-V-101

100-P-1 03A/B FEED OIL

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

306899 32610

0 339509

439 339.1


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr @1 Total Vap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




111 111A 111B 112 10 O-P-1 03AIB SPLIT SPLIT VALVE

SPLIT VALVE MIX MIX FEED OIL FEED OIL FD OIL BYPASS FEED OIL

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

306899 276209 30690 276209 32610 29349 3261 29349

0 0 0 0 339509 305558 33951 305558

439 395 44 395 339.1 305.2 33.9 305.2

MAT BAL REFLECTS A 0.1% CONVERGENCE OF THE PROCESS MODEL.


I Eng: IAprvd:

I Page

112A MIX

100-E-103 FEED OIL

6801 1 0

31 766 289 248

85 72

0 0

113 1 0 0

276209 29349

0 313965

3836

I Date: 06/13/2014

2 of 301

11 3 100-E-103 100-H-101 FEED OIL

6801 1 0

31 766 289 248

85 72

0 0

113 1 0 0

276209 29349

0 313965

3836


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr @1 Total Yap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Yap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




114 114A 115 116 100-H-101 MIX 100-R-101 100-Y-103

MIX 100-R-101 100-Y-103 MIX FURNACE EFF REACTOR FEED REACTOR EFF INTERSTG YAP

6801 6801 4252 3907 1 1 6451 5346 0 0 352 295

31 31 531 464 766 766 2233 1988 289 289 1466 1255 248 248 1639 1354

85 85 701 562 72 72 689 545

0 0 0 0 0 0 0 0

113 113 12046 7709 1 1 41557 13575 0 0 88640 5367 0 0 153408 171

276209 276209 0 0 29349 29349 0 0

0 0 0 0 313965 313965 313965 42538

3836 3836 3321 2515



I Eng: IAprvd:

I Page

117 MIX

100-Y-103 QUENCH OIL

1 9 0 1 1 2 5 4 4 0 0

346 3374 1236

16 30690

3261 0

38950 67

39.8

I Date: 06/13/2014

3 of 301

118 100-Y-103

MIX INTRSTG LIQ

347 1114

57 68

246 214 290 143 148

0 0

4683 31356 84510

153253 30690

3261 0

310380 877

324.2

COMPONENT SUMMARY




START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'ihr @1 Total Vap. Std. Flow, Nm'ihr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

119 MIX

100-R-102 2ND RXTR FEED

6649 1114

57 97

956 482 520 222 215

0 0

4788 31 357 84510

153253 30690

3261 0

318171 4067


120 121 100-R-102 MIX

MIX MIX 2ND RXTR EFF 2ND RXTR EFF

4798 8705 4740 10086

204 498 399 862

2756 4744 2045 3300 2329 3683 1116 1678 1109 1654

0 0 0 0

17921 25630 74113 87688

103867 109234 102774 102946

0 0 0 0 0 0

318171 360708 3794 6308



I Eng:

121A MIX MIX

2ND RXTR EFF

12783 10087

498 881

5203 3474 3832 1729 1697

0 0

25698 87689

109234 102946

0 0 0

365751 8371

IAprvd:

I Page

121B MIX

100-V-104 HP/HT SEP IN

12787 10118

500 884

5208 3482 3850 1742 1713

0 0

26954 99931

113720 103005

0 0 0

383894 8461

I Date: 06/13/2014

4 of 301

122 100-V-104

MIX HP/HT VAP

12388 9378 466 828

4978 3271 3558 1587 1551

0 0

21724 49516 11669

154 0 0 0

121068 7542

169051.7


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5-165C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'/hr @1 Total Yap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5-165C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Yap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




122A 1228 122C 123 MIX 100-E-102 100-E-103 100-Y-104

100-E-102 100-E-103 100-E-105 LETDOWN HP/HT YAP HP/HT YAP HP/HT YAP HP/HT LIQ

17846 17846 17846 398 10728 10728 10728 741

622 622 622 34 1058 1058 1058 55 6635 6635 6635 230 4403 4403 4403 211 4882 4882 4882 292 2240 2240 2240 156 2190 2190 2190 162

0 0 0 0 0 0 0 0

28661 28661 28661 5229 69009 69009 69009 50415 16249 16249 16249 102051

215 215 215 102851 0 0 0 0 0 0 0 0 0 0 0 0

164738 164738 164738 262825 10690 10690 10690 920

283.3 239519.8



I Eng: IAprvd:

I Page

123A MIX

100-Y-105 HP/HT LIQ

398 741

34 55

230 211 292 156 162

0 0

5229 50415

102051 102851

0 0 0

262825 920

I Date: 06/13/2014

5 of 301

124 100-Y-105

MIX MP/HT YAP

355 560

26 46

194 167 218 110 112

0 0

2462 7912 1906

20 0 0 0

14088 290

6537.0


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'/hr @1 Total Yap. Std. Flow, Nm'ihr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq . Std. Flow, m'/hr@1 Total Yap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




124A 1248 125 125A MIX 100-E-112A/B 100-Y-105 LETDOWN

100-E-112A/B MIX LETDOWN 100-T-301 MP/HT YAP MP/HT YAP MP/HT OIL MP/HT OIL

470 470 44 44 619 619 181 181

33 33 8 8 56 56 9 9

242 242 35 35 210 210 44 44 278 278 74 74 143 143 46 46 146 146 50 50

0 0 0 0 0 0 0 0

3040 3040 2768 2768 10189 10189 42502 42502 2474 2474 100145 100145

26 26 102832 102832 0 0 0 0 0 0 0 0 0 0 0 0

17926 17926 248738 248738 377 377 625 625

260.7 8457.0



I Eng: IAprvd:

I Page 6 of 301

126 126A 100-E-101 100-E-104 100-E-104 100-Y-108

HP/HT YAP HP/MT SEP FD

17846 10728

622 1058 6635 4403 4882 2240 2190

0 0

28661 69009 16249

215 0 0 0

164738 10690

I Date: 06/13/2014

17846 10728

622 1058 6635 4403 4882 2240 2190

0 0

28661 69009 16249

215 0 0 0

164738 10690


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'ihr @1 Total Vap. Std. Flow, Nm'ihr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




127 128 128A 129 100-V-108 100-V-108 LETDOWN MIX

MIX LETDOWN MIX 100-A-101 HP/MTVAP HP/MT OIL HP/MT OIL HP/MT FSH GAS

17709 138 138 17709 10406 322 322 1042S

603 19 19 613 1021 37 37 2S940 6S41 94 94 6S41 4297 106 106 4297 4710 172 172 4710 2136 104 104 2136 2078 112 112 2078

0 0 0 0 0 0 0 0

236S4 S008 S008 236S4 26S4S 42464 42464 26S4S

408 1S841 1S841 408 0 21S 21S 0 0 0 0 0 0 0 0 0 0 0 0 0

100108 64632 64632 12SOS6 10292 39S 39S 11677

77.8 230679.6



I Eng: IAprvd:

I Page

129A 100-A-101 100-V-109

HP/MT FSH GAS

17709 1042S

613 2S940

6S41 4297 4710 2136 2078

0 0

236S4 26S4S

408 0 0 0 0

12SOS6 11677

I Date: 06/13/2014

7 of 301

130 100-V-109 100-V-112

HP/LTVAP

17618 7734

2 132

6368 3880 3632 134S 114S

0 0

1668 37

0 0 0 0 0

43S61 9644

2161SS.9


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




131 131A 131B 132 100-V-109 LETDOWN MIX 100-V-109

LETDOWN MIX MIX LETDOWN HP/LT OIL HP/LT OIL HP/LT OIL SOUR WATER

83 83 88 8 1213 1213 1213 1478

0 0 0 611 20 20 20 2S789

170 170 217 3 41S 41S S06 2

1077 1077 1264 1 791 791 908 0 932 932 10S6 0

0 0 0 0 0 0 0 0

21986 21986 22S94 0 26S08 26S08 26S37 0

408 408 408 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

S3603 S3603 S4811 27892 S16 S16 S41 1S16

72.S 28.8



I Eng: IAprvd:

I Page

132A LETDOWN

MIX SOUR WATER

8 1478 611

2S789 3 2 1 0 0 0 0 0 0 0 0 0 0 0

27892 1S16

I Date: 06/13/2014

B of 301

133 100-V-112 100-T-101

SOUR GAS

17618 7734

2 132

6368 3880 3632 134S 114S

0 0

1668 37

0 0 0 0 0

43S61 9644

2161SS.9


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'/hr @1 Total Vap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




134 13S 136 136A 100-T-101 100-V-113 SPLIT 100-E-110 1 OO-V-113 SPLIT 100-E-110 100-ME-101

SWEET GAS SWEET GAS SWEET GAS MEM FEED

17S88 17S88 149SO 149SO s s 4 4 0 0 0 0

114 114 98 98 63SS 63SS S402 S402 3873 3873 3292 3292 3626 3626 3083 3083 134S 134S 1144 1144 114S 114S 973 973

0 0 0 0 0 0 0 0

166S 166S 1416 1416 37 37 31 31

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

3S7S3 3S7S3 30393 30393 9399 9399 7990 7990

210664 .S 210664.S 179082.2 179082.2



I Eng: IAprvd:

I Page 9 of 301

137 138 SPLIT 100-ME-101

MIX MIX SWEET GAS 1STSTG PERM

2638 1 0

17 9S3 S81 S44 202 172

0 0

2SO s 0 0 0 0 0

S363 1411

31600 .0

I Date: 06/13/2014

13494 3 0

93 1231 4S3 343 102 87

0 0

1SS 0 0 0 0 0 0

1S961 6803

1S2493.S

COMPONENT SUMMARY




START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'ihr @1 Total Vap. Std. Flow, Nm'ihr


138A MIX MIX

1ST STG PERM

16132 4 0

110 2184 1034 887 303 258

0 0

404 5 0 0 0 0 0

21321 8213

184086.6


139 139A 100-ME-101 100-E-115

100-E-115 MIX 2ND STG PERM 2ND STG PERM

1233 1233 0 0 0 0 4 4

858 858 305 305 227 227

68 68 57 57

0 0 0 0

67 67 0 0 0 0 0 0 0 0 0 0 0 0

2819 2819 684 684

15321.3 15321.3



I Eng:

140 100-ME-101

MIX NP OIL

5 0 0 0

47 91

188 117 123

0 0

609 29

0 0 0 0 0

1209 22

IAprvd:

I Page

141 100-ME-101

MIX NP GAS

218 0 0 0

3267 2443 2325

856 707

0 0

585 2 0 0 0 0 0

10403 480

10745.8

I Date: 06/13/2014

10 of 301

144 MIX

100-E-113 MP/HTVAP

608 941

52 93

336 316 450 247 259

0 0

8048 52654 18316

241 0 0 0

82561 770


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr @1 Total Vap. Std. Flow, Nm'ihr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq . Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY


LCMAX RESIDUE HYDROCRACKING PLANT SHANDONG SINCIER PETROCHEMICAL CO., LTD.


144A 14S 146 147 1 OO-E-113 100-V-110 100-V-110 MIX 1 OO-V-110 MIX MIX 100-E-114

MP/MTVAP MP/MTVAP MP/MT LIQ MP/MTVAP

608 S91 17 S91 941 813 128 817

S2 44 7 47 93 82 11 SS32

336 317 20 317 316 282 34 282 4SO 37S 74 37S 247 193 S4 193 2S9 19S 63 19S

0 0 0 0 0 0 0 0

8048 2927 S121 2927 S26S4 2728 49926 2728 18316 20 18296 20

241 0 241 0 0 0 0 0 0 0 0 0 0 0 0 0

82S61 8S67 73992 14024 770 414 3S7 716

86.S 92S1.3



I Eng: IAprvd:

I Page

147A 100-E-114 100-V-111

MP/LTVAP

S91 817

47 SS32

317 282 37S 193 19S

0 0

2927 2728

20 0 0 0 0

14024 716

I Date: 06/13/2014

11 of 301

148 100-V-111 100-V-124

MP/LTVAP

S90 636

0 22

312 263 30S 127 112

0 0

176 3 0 0 0 0 0

2S46 3SS

7931 .3


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr @1 Total Vap. Std. Flow, Nm'/hr


COMPONENT SUMMARY




148A 149 149A 150 1 OO-V-124 100-V-111 VALVE 100-V-111 100-T-102 VALVE MIX VALVE

MP/LTVAP MP/LT OIL MP/LT OIL SOUR WATER

590 1 1 0 636 64 64 117

0 0 0 47 22 1 1 SS09

312 s s 0 263 19 19 0 30S 70 70 0 127 6S 6S 0 112 83 83 0

0 0 0 0 0 0 0 0

176 27S1 27S1 0 3 2726 2726 0 0 20 20 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

2S46 5805 S80S S673 3SS 47 47 313

7.7 S.8 7931.3



I Eng: IAprvd:

I Page

150A VALVE

MIX SOUR WATER

0 117 47

SS09 0 0 0 0 0 0 0 0 0 0 0 0 0 0

S673 313

I Date: 06/13/2014

12 of 301

151 100-T-102 100-V-125

SWEET GAS

590 1 0

31 312 263 30S 127 112

0 0

176 3 0 0 0 0 0

1920 337

7S24 .9



END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq . Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




151A 1518 152 153 1 DD-V-125 VALVE MIX MIX

VALVE MIX 100-V-123 100-P-105A/B OFF GAS OFF GAS MP/LT OIL QUENCH OIL

590 590 89 7 1 1 1277 50 0 0 0 3

31 31 21 4 312 312 221 8 263 263 525 13 305 305 1334 29 127 127 973 21 112 112 1138 24

0 0 0 0 0 0 0 0

176 176 25345 1994 3 3 29263 19441 0 0 428 7125 0 0 0 94 0 0 0 0 0 0 0 0 0 0 0 0

1920 1920 60614 28813 337 337 592 137

33.7 7524.9 7524.9



I Eng: IAprvd:

I Page

153A 1 DD-P-1 D5A/B

100-A-104 QUENCH OIL

7 50

3 4 8

13 29 21 24

0 0

1994 19441 7125

94 0 0 0

28813 137

33.7

I Date: 06/13/2014

13 of 301

154 100-A-104

SPLIT QUENCH OIL

7 50

3 4 8

13 29 21 24

0 0

1994 19441 7125

94 0 0 0

28813 137

33.7




COMPONENT SUMMARY




155 155A 155B 156 SPLIT SPLIT SPLIT SPLIT SPLIT MIX MIX MIX

QUENCH OIL QUENCH OIL QUENCH OIL QUENCH OIL

5 1 4 1 40 9 31 10

2 0 2 0 4 1 3 1 6 1 5 1

11 2 9 3 23 5 18 6 17 4 14 4 20 4 15 5

0 0 0 0 0 0 0 0

1602 346 1256 392 15616 3374 12242 3826 5722 1236 4486 1402

75 16 59 19 0 0 0 0 0 0 0 0 0 0 0 0

23143 4999 18144 5670 110 23 86 27

27.1 5.8 21.2 6.6



I Eng: IAprvd:

I Page

157 SPLIT

VALVE MP/MT OIL

10 78

5 7

12 21 45 33 39

0 0

3127 30484 11171

147 0 0 0

45179 218 52.8

I Date: 06/13/2014

14 of 301

157A VALVE

MIX MP/MT OIL

10 78

5 7

12 21 45 33 39

0 0

3127 30484 11171

147 0 0 0

45179 218


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'/hr @1 Total Vap. Std. Flow, Nm'/hr


COMPONENT SUMMARY




159 160 160A 161 OSBL MIX 100-ME-107 100-ME-107

MIX 100-ME-107 MIX MIX MU H2 2ND STG PERM TAIL GAS PSAH2

6746 1823 274 1550 0 1 1 0 0 0 0 0 0 35 35 0

542 1170 1158 12 0 567 567 0 0 532 532 0 0 196 196 0 0 170 170 0 0 0 0 0 0 0 0 0 0 243 243 0 0 3 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

7288 4740 3179 1562 3380 1019 250 770

75766 .8 22852.7 5604.4 17255.1



I Eng: IAprvd:

I Page 15 of 301

162 163 MIX 100-V-116

100-V-116 100-C-101ABC H2 1ST STG SUCT

8296 0 0 0

554 0 0 0 0 0 0 0 0 0 0 0 0 0

8850 4149

92997 .6

I Date: 06/13/2014

8296 0 0 0

554 0 0 0 0 0 0 0 0 0 0 0 0 0

8850 4149

92997.6

COMPONENT SUMMARY




START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'ihr @1 Total Yap. Std. Flow, Nm'/hr



163A 164 165 100-C-101ABC 100-E-107ABC 100-V-117ABC 100-E-107ABC 100-V-117ABC 100-C-101ABC

1STSTG DSCH COOL 1ST STG 2ND STG SUCT

8296 8296 8296 0 0 0 0 0 0 0 0 0

554 554 554 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

8850 8850 8850 4149 4149 4149

92997 .6 92997.6 92997 .6



I Eng:

166 100-C-101ABC

MIX 2ND STG DSCH

8296 0 0 0

554 0 0 0 0 0 0 0 0 0 0 0 0 0

8850 4149

92997.6

IAprvd:

I Page 16 of 301

167 168 MIX 1 OO-E-108ABC

1 OO-E-108ABC 1 OO-V-118ABC 2ND STG DSCH COOL2ND STG

24428 4 0

110 2738 1034 887 303 258

0 0

404 5 0 0 0 0 0

30171 12363

277039.2

I Date: 06/13/2014

24428 4 0

110 2738 1034 887 303 258

0 0

404 5 0 0 0 0 0

30171 12363

277039.2

COMPONENT SUMMARY




START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'ihr @1 Total Vap. Std. Flow, Nm'/hr


169 100-V-118ABC 100-C-101ABC

3RD STG SUCT

24428 4 0

110 2738 1034 887 303 258

0 0

404 5 0 0 0 0 0

30171 12363

277039.2


169A 169B 100-C-101ABC SPLIT

SPLIT OSBL RECYCLE GAS SYSTEM LEAKS

24312 116 4 0 0 0

110 0 2738 0 1034 0 887 0 303 0 258 0

0 0 0 0

404 0 5 0 0 0 0 0 0 0 0 0 0 0

30055 116 12305 58

275748.2 1289.7



I Eng:

170 SPLIT

MIX RECYCLE GAS

2375 0 0

11 268 101 87 29 25

0 0

39 0 0 0 0 0 0

2935 1200

26928.0

IAprvd:

I Page 17 of 301

171 SPLIT SPLIT

RECYCLE GAS

4387 1 0

20 494 186 160 55 47 0 0

73 1 0 0 0 0 0

5424 2221

49764 .0

I Date: 06/13/2014

171A SPLIT

MIX RECYCLE GAS

309 0 0 1

35 13 11 4 3 0 0 5 0 0 0 0 0 0

381 155

3495 .6




COMPONENT SUMMARY




1718 172 173 173A SPLIT SPLIT 100-E-101 SPLIT

MIX 100-E-101 SPLIT MIX RECYCLE GAS RECYCLE GAS RECYCLE GAS RECYCLE GAS

4077 17550 17550 1120 0 3 3 0 0 0 0 0

19 79 79 5 459 1976 1976 126 173 747 747 48 149 640 640 41

51 219 219 14 43 186 186 12 0 0 0 0 0 0 0 0

68 292 292 19 1 4 4 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

5040 21696 21696 1385 2065 8884 8884 566

46240.9 199056.1 199056.1 12707.1



I Eng: IAprvd:

I Page 18 of 301

174 100-E-102

SPLIT RECYCLE GAS

16430 3 0

74 1850 699 600 205 175

0 0

274 4 0 0 0 0 0

20314 8316

186376.6

I Date: 06/13/2014

175 SPLIT SPLIT

RECYCLE GAS

4755 1 0

21 536 202 174 59 50

0 0

79 1 0 0 0 0 0

5878 2408

53929.4




COMPONENT SUMMARY




175A 1758 176 177 SPLIT SPLIT SPLIT SPLIT

MIX MIX SPLIT SPLIT RECYCLE GAS RECYCLE GAS RECYCLE GAS RECYCLE GAS

713 4042 11674 6801 0 0 2 1 0 0 0 0 3 18 53 31

80 455 1315 766 30 172 497 289 26 147 426 248

9 50 146 85 8 43 124 72 0 0 0 0 0 0 0 0

12 67 194 113 0 1 3 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

881 4995 14434 8407 360 2047 5909 3441

8083.0 45828.1 132428.8 77132.4



I Eng: IAprvd:

I Page 19 of 301

177A 178 SPLIT SPLIT

MIX VALVE RECYCLE GAS RECYCLE GAS

6801 1 0

31 766 289 248

85 72

0 0

11 3 1 0 0 0 0 0

8407 3441

77132.4

I Date: 06/13/2014

4873 1 0

22 549 207 178

61 52

0 0

81 1 0 0 0 0 0

6025 2467

55278.1




COMPONENT SUMMARY




178A 179 181 182 VALVE MIX OSBL MIX

MIX MIX MIX 100-V-119 RECYCLE GAS RECYCLE GAS STRPPD WATER WATER

4873 6303 0 0 1 1 0 27 0 0 0 14

22 29 22440 34901 549 710 0 0 207 268 0 0 178 230 0 0

61 78 0 0 52 67 0 0

0 0 0 0 0 0 0 0

81 105 0 0 1 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

6025 7792 22440 34942 2467 3189 1246 1939

22 .5 35.0 55278 .1 71489.9



I Eng: IAprvd:

I Page 20 of 301

182A 100-V-119

SPLIT WASH WATER

0 27 14

34901 0 0 0 0 0 0 0 0 0 0 0 0 0 0

34942 1939 35.0

I Date: 06/13/2014

183 SPLIT

100-P-106A/8 WASH WATER

0 23 12

29451 0 0 0 0 0 0 0 0 0 0 0 0 0 0

29486 1636 29.6




COMPONENT SUMMARY




184 185 185A 186 100-P-106AIB SPLIT VALVE SPLIT

SPLIT VALVE MIX VALVE HP WASH HP WASH HP WASH HP WASH

0 0 0 0 23 19 19 4 12 10 10 2

29451 24920 24920 4531 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

29486 24949 24949 4537 1636 1383 1383 251 29.6 25 .0 25.0 4.6



I Eng: IAprvd:

I Page 21 of 301

186A VALVE

100-T-101 HP WASH

0 4 2

4531 0 0 0 0 0 0 0 0 0 0 0 0 0 0

4537 251 4 .6

I Date: 06/13/2014

187 100-T-101 100-T-101

SOUR WATER

1 2 1

4613 0 0 0 0 0 0 0 0 0 0 0 0 0 0

4617 256 4.6




COMPONENT SUMMARY REACTION AND SEPARATION



188 189 189A 190 SPLIT 100-P-109A/B VALVE OSBL

10 O-P-1 09A/B VALVE MIX SPLIT WASH WATER MP WASH MP WASH LEAN AMINE

0 0 0 0 4 4 4 265 2 2 2 0

5450 5450 5450 138946 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 92642

5456 5456 5456 231853 303 303 303 8497 5.5 5.5 5.5 228.5



I Eng: IAprvd:

I Page

191 SPLIT

VALVE LEAN AMINE

0 205

0 107284

0 0 0 0 0 0 0 0 0 0 0 0 0

71531 179020

6561 176.4

I Date: 06/13/2014

22 of 301

191A VALVE

100-E-116 LEAN AMINE

0 205

0 107284

0 0 0 0 0 0 0 0 0 0 0 0 0

71531 179020

6561 176.4




COMPONENT SUMMARY




1918 192 193 193A 1 OO-E-116 100-V-120 100-P-1 07 A/B VALVE 100-V-120 100-P-107A/B VALVE 100-T-101

LEAN AMINE LEAN AMINE HP LEAN AMINE HP LEAN AMINE

0 0 0 0 205 205 205 205

0 0 0 0 107284 107284 107284 107284

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

71531 71531 71531 71531 179020 179020 179020 179020

6561 6561 6561 6561 176.4 176.4 176.4 176.4



I Eng: IAprvd:

I Page

194 100-T-101

LETDOWN RICH AMINE

30 7937

4 111832

13 7 6 0 0 0 0 3 0 0 0 0 0

71531 191363

7056 191 .3

I Date: 06/13/2014

23 of 301

194A LETDOWN

MIX RICH AMINE

30 7937

4 111832

13 7 6 0 0 0 0 3 0 0 0 0 0

71531 191363

7056



END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m' /hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




195 195A 196 196A SPLIT 100-P-108A/B SPLIT VALVE

10 O-P-1 08A/B SPLIT VALVE 100-T-102 LEAN AMINE LP LEAN AMINE LP LEAN AMINE LP LEAN AMINE

0 0 0 0 60 60 17 17

0 0 0 0 31662 31662 8764 8764

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

21111 21111 5843 5843 52833 52833 14624 14624

1937 1937 535 535 52 .1 52 .1 14.4 14.4



I Eng: IAprvd:

I Page

197 100-T-102

VALVE RICH AMINE

0 652

0 8755

0 0 0 0 0 0 0 0 0 0 0 0 0

5843 15250

554 15.2

I Date: 06/13/2014

24 of 301

197A VALVE

MIX RICH AMINE

0 652

0 8755

0 0 0 0 0 0 0 0 0 0 0 0 0

5843 15250

554 15.2



END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq . Std. Flow, m'/hr@1 Total Yap. Std. Flow, Nm'/hr

COMPONENT SUMMARY




1978 198 198A 199 MIX 100-V-122 VALVE MIX

100-V-122 VALVE OS8LARU 100-V-121 RICH AMINE RICH AMINE RICH AMINE SOUR WATER

30 6 6 8 8589 8554 10239 1595

4 4 5 657 120587 120580 143351 31466

13 2 3 3 8 2 3 2 6 1 2 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

77374 77374 92642 0 206614 206523 246251 33732

7610 7596 9037 1836 206.1 245.7



I Eng: IAprvd:

I Page 25 of 301

199A 100-V-121

VALVE SOUR WATER

0 1519 657

31464 0 0 0 0 0 0 0 0 0 0 0 0 0 0

33640 1829 34.5

I Date: 06/13/2014

1998 VALVE

OS8L SOUR WATER

0 1519 657

31464 0 0 0 0 0 0 0 0 0 0 0 0 0 0

33640 1829


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5-165C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr @1 Total Vap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5-165C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Vap. Std. Flow, Nm'/hr

COMPONENT SUMMARY



199C 1 OO-V-121

MIX SOUR GAS

8 76

0 2 3 2 1 0 0 0 0 0 0 0 0 0 0 0

92 6

142.1




I Eng: IAprvd:

I Page 26 of 301

I Date: 06/13/2014


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165-360C 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'ihr @1 Total Vap. Std. Flow, Nm'/hr


COMPONENT SUMMARY




201 202 203 OSBLSDA 100-E-408 SPLIT 1 OO-E-408 SPLIT MIX

DAO DAO DAO

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

107849 107849 75239 0 0 0

107849 107849 75239 145 145 101

108.4 108.4 75.6


203A SPLIT

MIX DAO

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

32610 0

32610 44

32.8


I Eng: IAprvd:

I Page

204 MIX

100-V-102 DAO

0 0 0 0 0 0 0 0 0 0 0 0 0

6585 12228

0 87559

0 106372

162 107.3

I Date: 06/13/2014

27 of 301

205 100-V-102

100-P-1 04A/B DAO

0 0 0 0 0 0 0 0 0 0 0 0 0

6585 12228

0 87559

0 106372

162 107.3

COMPONENT SUMMARY I Page 28 of 301 REACTION AND SEPARATION



Stream No 206 208 208A 209 210 211 From 100-P-104AIB VALVE MIX 100-H-102 MIX 100-R-103 To VALVE MIX 100-H-102 100-ME-104 100-R-103 MIX Content 2ND STG FEED 2ND STG FEED 2ND STG FEED FURNACE EFF DAO RXTR FEED DAO RXTR EFF



0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

6585 6585 12228 12228

0 0 87559 87559

0 0 106372 106372

162 162 107.3 107.3



I Eng:

713 713 0 0 0 0 3 3

80 80 30 30 26 26

9 9 8 8 0 0 0 0

12 12 0 0

6585 6585 12228 12228

0 0 87559 87559

0 0 107253 107253

522 522

IAprvd:

4755 1 0

21 536 202 174 59 50

0 0

79 1

6585 12228

0 87559

0 112250

2570

I Date: 06/13/2014

3213 1420

164 229

1445 1084 1313 668 660

0 0

7794 31046 39324 23892

0 0 0

112252 2194

COMPONENT SUMMARY




START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'/hr @1 Total Yap. Std. Flow, Nm'/hr

END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow , kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Yap. Std. Flow, Nm'/hr

212 MIX MIX

DAO RXTR EFF

5588 1420

164 240

1713 11B5 1400 69B 684

0 0

7B33 31046 39324 23892

0 0 0

115187 3397


212A 213 MIX 100-Y-106

100-Y-106 MIX DAO RXTR EFF HP/HT YAP

5590 5459 1430 1350

165 156 241 230

1714 1657 1187 1133 1405 1324 702 654 6B9 639

0 0 0 0

B225 6937 34872 19493 40726 4581 23911 61

0 0 0 0 0 0

120B57 43674 3423 3144

70475 .8



I Eng:

214 100-Y-106

LETDOWN HP/HT LIQ

131 BO 9

11 57 55 B2 49 50 0 0

128B 15379 36145 23849

0 0 0

77185 279 84.1

IAprvd:

I Page

215 LETDOWN

100-Y-107 HP/HT LIQ

131 BO

9 11 57 55 B2 49 50

0 0

1288 15379 36145 23849

0 0 0

77185 279

I Date: 06/13/2014

29 of 301

216 100-Y-107

MIX MP/HT YAP

116 59

6 10 4B 43 60 34 34

0 0

578 2277

569 6 0 0 0

3840 83

1921 .0




COMPONENT SUMMARY



217 100-V-107

LETDOWN MP/HT LIQ

15 20 2 2

10 12 22 15 16

0 0

710 13102 35576 23843

0 0 0

73345 191

77.7


218 LETDOWN

100-T-303 MP/HT OIL

15 20

2 2

10 12 22 15 16

0 0

710 13102 35576 23843

0 0 0

73345 191



I Eng: IAprvd:

I Page 30 of 301

I Date: 06/13/2014

STREAM DATA SHEETS


LCMAX RESIDUE HYDROCRACKING PLANT SHANDONG SINCIER PETROCHEMICAL CO. , LTD.


START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard , m'/hr @15.6° Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, °C Pseudo Crit Temp, 'C Pressure , Mpa (g) Pseudo Crit Pres. Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density, kg/m' Liqu id Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density. kg/m' Vapor Viscosity. cP Vapor K. W/m/'C Vapor Spec Heat, kJ/kg/'C Vapor Mol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass. kg/h r Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard , m'/[email protected]' Flow Condition, m'/hr Flow Condition, m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density, kg/m3

Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat , kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy , MW

101 OSBL

100-E-405 FEED OIL

306899 395

306.4

328.7

156 796

1.00 0.87

0.0 9.5

933.7 122.940

0.080 2.303

280.0 23.9

•Datum H20 and HC Above 15.6'C Liquid H2 Above 15.6' C Vapor


102 100-E-405 100-E-406 FEED OIL

306899 395

306.4

333.8

185 796

0.90 0.87

0.0 9.5

919.5 46.174

0.078 2.407

350.0 29.8

103 100-E-406 100-E-407 FEED OIL

306899 395

306.4

341.9

232 796

0.79 0.87

0.0 9.5

897.6 15.352 0.075 2.563

464.8 39.6

MAT BAL REFLECTS A 0.1 % CONVERGENCE OF THE PROCESS MODEL.

Confidential II Eng: IChkd:

104 100-E-407

MIX FEED OIL

306899 395

306.4

346.7

257 796

0.69 0.87

0.0 9.5

885.1 9.648 0.073 2.647

< 0.01

531.7 45.3

IAprvd:

I Page

105 VALVE

100-V-101 FEED OIL

339509 439

339.1

383.8

254 793

0.41 0.89

0.0 9.6

884.5 10.071 0.073 2.637

524.1 49.4

I Date: nc;: 1 1 ~ / "') (1 1 ,.,

1 of 301

110 100-V-1 01

100-P-1 03NB FEED OIL

339509 439

339.1

384 .0

254 793

0.35 0.89

0.0 9.6

884.2 10.052 0.072 2.638

< 0.01

524 .1 49.4

!Rev: n

STREAM DATA SHEETS


LCMAX RESIDUE HYDROCRACKING PLANT SHAN DONG SINCIER PETROCHEMICAL CO., LTD.


START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/hr@ 15.6' Flow Condition, m'/hr Flow Condition, m' /hr

Temperature , °C Pseudo Crit Temp, 'C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/°C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/"C VaporMolWt Entha lpy, kJ/kg Entha lpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'ihr Flow Standard, m3/[email protected]' Flow Condition, m' /hr Flow Condition, m' /hr

Temperature , °C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/mi'C Liquid Spec Heat, kJ/kg/°C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/°C VaporMolWt Enthalpy, kJ/kg Enthalpy. MW

111 100-P-103A/B

SPLIT FEED OIL

339509 439

339.1

371.3

257 793

19.95 0.89

0.0 9.6

914.3 14.140 0.082 2.638

553.6 52.2

•Datum H20 and HC Above 15.6'C Liquid H2 Above 15.6°C Vapor



VALVE MIX FEED OIL FD OIL BYPASS

305558 33951 395 44

305.2 33.9

334.2 37.1

257 257 793 793

19.95 19.95 0.89 0.89

0.0 0.0 9.6 9.6

914.3 914.3 14.140 14.140 0.082 0.082 2.638 2.638

< 0.01 < 0.01

553.6 553.6 47 .0 5.2



112 VALVE

MIX FEED OIL

305558 395

305.2

334.4

257 793

19.26 0.89

0.0 9.6

913.8 13.887 0.082 2.639

553.6 47.0

IAprvd:

I Page 2 of 301

112A 113 MIX 100-E-103

100-E-103 100-H-101 FEED OIL FEED OIL

313965 313965 3836 3836

270 288

19.26 19.14

2.6 2.6

886.9 877.6 10.963 8.432 0.070 0.068 2.690 2.744

17 16

9.62 9.30 0.012 0.013 0.213 0.218

12.595 12.577 2.4 2.4

690.2 742.1 60.2 64.7

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS





START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/h [email protected]' Flow Condition, m'/hr Flow Condition, m' /hr

Temperature , °C Pseudo Grit Temp, 'C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt% Vaporized Liquid Deg API



END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'ihr Flow Standard, m3/[email protected]' Flow Condition, m'/hr Flow Condition, m' /hr

Temperature , °C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/°C VaporMolWt Enthalpy, kJ/kg Enthalpy. MW

114 100-H-101

MIX FURNACE EFF

313965 3836

374

18.07

2.6

827.3 3.138 0.056 2.994

9

7.89 0.014 0.241

12.361 2.5

1010.7 88.2

114A MIX

100-R-101 REACTOR FEED

313965 3836

374

18.00

2.6

827.2 3.134 0.056 2.994

9

7.86 0.014 0.241

12.360 2.5

1010.7 88.2



Confidential II Eng:

115 100-R-101 100-V-103

REACTOR EFF

313965 3321

430

17.61

13.5

706.7 0.147 0.049 3.106

0

47.88 0.024 0.192 3.881

16.9 1160.2

101.2

IChkd:

116 100-V-103

MIX INTERSTG VAP

42538 2515

418

17.59

99.9

688.4 0.137 0.053 3.102

0

48.60 0.024 0.187 3.859

16.9 1803.4

21.3

IAprvd:

I Page 3 of 301

117 118 MIX 100-V-103

100-V-103 MIX QUENCH OIL INTRSTG LIQ

38950 310380 67 877

39.8 324.2

43 9 436.1

245 410 663 419

17.59 17.59 1.38 1.97 0.0 0.0

12.7 16.0

886.3 711 .7 1.902 0.159 0.077 0.049 2.602 3.060

17.69

522.9 992.1 5.7 85.5

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS



DONGYING , P.R. CHINA


START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/[email protected]° Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, °C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres. Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density , kg/m' Liquid Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density. kg/m' Vapor Viscosity, cP Vapor K. W/m/'C Vapor Spec Heat, kJ/kgi°C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/[email protected] ' Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density , kg/m3

Liquid Viscosity, cP Liquid K, W/m/' C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density , kg/m' Vapor Viscosity , cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

119 120 MIX 100-R-102

100-R-102 MIX 2ND RXTR FEED 2ND RXTR EFF

318171 318171 4067 3794

402 435

17.23 16.84

7.6 20.1

750.2 693.5 0.1 85 0.132 0.052 0.052 3.033 3.144

3 0

21.00 59.45 0.020 0.025 0.209 0.203 5.901 3.731

7.2 22.2 1097.5 1209.9

97.0 106.9

•Datum H20 and HC Above 15.6' C Liqu id H2 Above 15.6' C Vapor



121 MIX MIX

2ND RXTR EFF

360708 6308

432

16.84

31.3

693.8 0.135 0.051 3.132

0

55.99 0.025 0.199 3.746 20.8

1279.9 128.2

IChkd:

121A MIX MIX

2ND RXTR EFF

365751 8371

416

16.84

33.2

696.6 0.143 0.051 3 089

0

44.29 0.024 0.199 4 .043

16.0 1298.5 131.9

IAprvd:

I Page 4 of 301

1218 122 MIX 100-V-104

100-V-104 MIX HP/HT SEP IN HP/HT VAP

383894 121068 8461 7542

169051 .7

2695.7

406 406 -165

16.82 16.82 2.06

31.5 100.0

692.5 0.1 43 0.052 3.067

0

44.91 44.91 0.023 0.023 0.194 0.194 4.021 4.021

16.1 16.1 1252.0 1822.0

133.5 61 .3

I Date: n~ 1 1 ~ / "') (1 1 ,.,

!Rev: n

STREAM DATA SHEETS




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/[email protected]' Flow Condition, m'/hr Flow Condition, m' /hr

Temperature , °C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/m/' C Liquid Spec Heat, kJ/kg/°C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/"C VaporMolWt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'ihr Flow Standard, m3/hr @15.6' Flow Condition, m'/hr Flow Condition, m'/hr

Temperature , °C Pseudo Cri t Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/mi'C Liquid Spec Heat, kJ/kg/°C Surface Tension, dyne/cm Liquid Vpr Press , Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/°C Vapor MolWt Enthalpy, kJ/kg Enthalpy. MW

122A MIX

100-E-102 HP/HT VAP

164738 10690

239519.8

3819.5

406 -170

16.82 1.97

100.0

43. 13 0.023 0.1 97 4. 110

15.4 1859.9

85.1



1228 122C 100-E-102 100-E-103 100-E-103 100-E-105

HP/HTVAP HP/HT VAP

164738 164738 10690 10690

372 350

16.68 16.51

94.7 88.0

659.9 650.9 0.128 0.129 0.058 0.059 3.033 2.979

0 0

42.84 41.04 0.022 0.022 0.181 0. 171 4. 106 4. 158

14 .7 13.7 1714 .0 1615.1

78.4 73 9



123 100-V-104

LETDOWN HP/HT LIQ

262825 920

283.3

379.5

406 374

16.82 1.94 0.0

20.7

692.5 0.143 0.052 3.067

16.92

989.4 72.2

IAprvd:

I Page 5 of 301

123A 124 MIX 100-V-105

100-V-105 MIX HP/HT LIQ MP/HTVAP

262825 14088 920 290

6537.0

589.0

409 409 -40

2.70 2.69 2.51

5.4 100.0

696.1 0.200 0.054 3.078

8

23.94 23.92 0.022 0.022 0. 165 0.165 3.097 3.097 48 .2 48.3

989.4 1356.8 72.2 5.3

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS









Temperature , °C Pseudo Cri t Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt % Vaporized Liquid Deg API



124A MIX

100-E-112NB MP/HTVAP

17926 377

8457.0

764.6

409 -45

2.68 2.42

100.0

23.45 0.022 0.169 3.118

47.5 1363.9

6.8

•Datum H20 and HC Above 15.6' C Liquid H2 Above 15.6°C Vapor


1248 125 100-E-112NB 100-V-105

MIX LETDOWN MP/HTVAP MP/HT OIL

17926 248738 377 625

260.7

357.3

260 409 567

2.50 2.69 1.67

43.1 0.0 16.5

679.3 696.2 0.212 0.200 0.073 0.054 2.721 3.078

10 2.79

13.78 0.019 0.110 3.117

23.5 806.6 968.6

4.0 66.9



125A LETDOWN 100-T-301

MP/HT OIL

248738 625

404

0.28

9.4

731.7 0.334 0.057 3.053

11

11 .50 0.014 0.066 2.802 163.3 968.6 66.9

IAprvd:

I Page 6 of 301

126 126A 100-E-101 100-E-104 100-E-104 100-V-108

HP/HT VAP HP/MT SEP FD

164738 164738 10690 10690

297 270

16.37 16.27

69.6 60.8

638.6 653.8 0.138 0.152 0.062 0.068 2.836 2.757

0 2

35 .86 33.02 0.020 0.019 0.150 0.1 42 4.418 4.625

11.0 9.7 1372.6 1249.3

62.8 57.2

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS








END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m3/[email protected]' Flow Condition, m'/hr Flow Condition, m' /hr




127 100-V-108

MIX HP/MTVAP

100108 10292

230679.6

3034.5

270 -188

16.25 1.96

100.0

32.99 0.019 0.142 4.625

9.7 1647.8

45.8



128 128A 100-V-108 LETDOWN

LETDOWN MIX HP/MT OIL HP/MT OIL

64632 64632 395 395

77.8

98.9

270 273 303

16.25 2.50 2.39

0.0 4.4 38.5

653.8 665.2 0.152 0.194 0.068 0.070 2.757 2.773

9 16.35

17.13 0.019 0.105 2.950

29.8 631.9 631 9

11.3 11.3



129 MIX

100-A-101 HP/MT FSH GAS

125056 11677

191

16.23

71.2

710.1 0.147 0.095 3.100

31

32.89 0.016 0.115 4.748

8.2 1377.4

47.9

IAprvd:

I Page

129A 100-A-101 100-V-109

HP/MT FSH GAS

125056 11677

50

16.10

36.3

795.3 0.482 0.143 2.740

54

26.14 0.012 0.106 6.919

4.7 460.7

16.0

!Date: n&:: 1 1 '=I /"n 1 J\

1 of 30 I

130 100-V-109 100-V-112

HP/LTVAP

43561 9644

216155.9

1726.4

50 -216

16.08 1.72

100.0

25.23 0.012 0.108 7.127

4.5 1008.0

12.2

IRev: n

STREAM DATA SHEETS




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/[email protected] ' Flow Condition, m' /hr Flow Condition , m' /hr


Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/m/' C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMolWt Enthalpy, kJ/kg Entha lpy, MW



Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/' C VaporMolWt Enthalpy, kJ/kg Enthalpy. MW

131 100-V-109

LETDOWN HP/LT OIL

53603 516

72.5

73.5

50 238

16.08 3.28

0.0 59.4

729.0 0.352 0.118 2066

16.18

122.9 1.8



131A 1318 LETDOWN MIX

MIX MIX HP/LT OIL HP/LT OIL

53603 54811 516 541

56 56

1.42 1.42

2.0 2.3

725.9 722.4 0.388 0.377 0.114 0.114 2.089 2.093

20 19

8.83 9.26 0.013 0.013 0.048 0.047 2.595 2.545

15.7 16.4 122.9 123.3

1.8 1 g



132 100-V-109

LETDOWN SOUR WATER

27892 1516

28.8

29.6

50 359

16.08 21.43

0.0 14.5

941.3 0.503 0.398 3.573

16.18

235.9 1.8

IAprvd:

I Page 8 of 301

132A 133 LETDOWN 100-V-112

MIX 100-T-101 SOUR WATER SOUR GAS

27892 43561 1516 9644

216155.9

1727.1

56 50 -216

0.82 16.07 1.72

0.4 100.0

937.8 0.463 0.396 3.626

64

5.25 25.22 0.013 0.012 0.078 0.108 2.106 7.127

15.4 4.5 2359 1008.0

1.8 12.2

!Date: n &:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS












134 100-T-101 100-V-113

SWEET GAS

35753 9399

210664.5

1744.4

60 -223

16.04 1.54

100.0

20.50 0.012 0.167 8.412

3.8 1199.5

11 .9



135 136 100-V-113 SPLIT

SPLIT 100-E-110 SWEET GAS SWEET GAS

35753 30393 9399 7990

210664.5 179082.2

1746.5 1485.8

60 60 -223 -223

16.02 16.00 1.54 1.54

100.0 100.0

20.47 20.46 0.011 0.011 0.120 0.120 8.405 8.405

3.8 3.8 1199.5 1199.5

11.9 10.1



136A 100-E-110

100-ME-101 MEM FEED

30393 7990

179082.2

1625.0

90 -223

15.90 1.54

100.0

18.70 0.011 0.128 8.452

3.8 1453. 1

12.3

IAprvd:

I Page 9 of 301

137 138 SPLIT 100-ME-101

MIX MIX SWEET GAS 1ST STG PERM

5363 15961 1411 6803

31600.0 152493.5

262.2 2314.0

60 94 -223 -236

16.00 9.28 1.54 1.36

100.0 100.0

20.46 6.90 0.011 0.010 0.120 0.158 8.405 12.759

3.8 2.3 1199.5 2187.5

1.8 9.7

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS













138A MIX MIX

1ST STG PERM

21321 8213

184086.6

2750.6

88 -234 9.27 1.39

100.0

7.75 0.010 0.149

11.647 2.6

1939.0 11 .5

139 100-ME-101

100-E-115 2ND STG PERM

2819 684

15321.3

961.1

100 -219 2.12 1.65

100.0

2.93 0.011 0.117 7.659

4 .1 1386.5

1.1




139A 100-E-115

MIX 2NDSTG PERM

2819 684

15321.3

832 9

40 -219 2.05 1.65

100.0

3.38 0.010 0.101 7.491

4 .1 934.5

0.7

IChkd:

140 100-ME-101

MIX NP OIL

1209 22

36

1.42

18.6

603.5 0.278 0.122 2.313

13

15.16 0.0 11 0.032 2.248

24.1 141.4

0

IAprvd:

I Page 10 of 301

141 144 100-ME-101 MIX

MIX 100-E-113 NP GAS MP/HTVAP

10403 82561 480 770

10745.8

950 9

61 269 -62

1.25 2.48 3.80

100.0 14.0

671 .8 0.201 0.071 2.755

10

10.94 15.38 0.012 0.019 0.037 0.109 2.354 3.034

21.7 26.8 454.3 669.8

1.3 15.4

!Date: n&:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS




START OF RU N Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard , m'/[email protected] ° Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, °C Pseudo Crit Temp, ' C Pressure , Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a )


END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard , Nm'/hr Flow Standard , m'/hr @15.6 ' Flow Condition, m'/hr Flow Condition, m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt % Vaporized Liquid Deg API



Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

144A 100-E-113 100-V-110

MP/MT VAP

82561 770

240

2.40

10.3

695.1 0.237 0.076 2.652

12

12. 11 0.018 0.103 3.159

20.7 581.4

13.3

•Datum H20 and HC Above 15.6' C Liquid H2 Above 15.6' C Vapor


145 146 100-V-110 100-V-110

MIX MIX MP/MT VAP MP/MT LIO

8567 73992 41 4 357

925 1.3 86.5

709.5 106.4

240 240 -124 428 2.39 2.39 2.53 2.26

100.0 0.0 33.6

695.2 0.237 0.076 2.652

12.07 0.018 0.103 3.157 20.8

1095.1 521.9 2.6 10.7

MAT BAL REFLECTS A 0. 1 % CONVERGENCE OF THE PROCESS MODEL.


147 MIX

100-E-114 MP/MT VAP

14024 716

136

2.37

41 .4

807.5 0.208 0. 142 3.387

48

9.62 0.015 0 073 3.279

13.2 775.2

3.0

IAprvd:

I Page 11 of 301

147A 148 100-E-114 100-V-11 1 100-V-111 100-V-124

MP/LT VAP MP/LT VAP

14024 2546 71 6 355

7931 .3

390.9

42 42 -1 91

2.30 2.28 2.1 4

19.2 100.0

841 .8 0.601 0.163 3.072

62

6.83 6.5 1 0.012 0.012 0.073 0.076 4.450 4.626

7.5 7.2 251.2 756.6

1.0 0.5

I Date: n~ 1 1 ~ / "') (1 1 ,.,

!Rev: n


START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/[email protected]' Flow Condition, m'/hr Flow Condition, m'/hr




END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m3/[email protected]' Flow Condition, m' /hr Flow Condition, m' /hr

Temperature , °C Pseudo Cri t Temp, ' C Pressure, Mpa (g) Pseudo Cri t Pres , Mpa (a) Wt% Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosi ty, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/°C VaporMolWt Enthalpy, kJ/kg Enthalpy. MW

STREAM DATA SHEETS



148A 100-V-124 100-T-102

MPILTVAP

2546 355

7931.3

392.0

42 -191 2.28 2.14

100.0

6.50 0.012 0.076 4.626

7.2 756.6

0.5


149 100-V-111

VALVE MP/LT OIL

5805 47

7.7

7.9

42 294

2.28 3.11

0.0 55.7

737 .0 0.464 0.119 2.031

2.38

86.0 0.1

149A VALVE

MIX MP/LT OIL

5805 47

42

1.42

0.1

736.5 0.465 0.118 2.034

21

5.70 0.012 0.062 3.593

9.8 86.0

0.1

150 100-V-1 11

VALVE SOUR WATER

5673 313

5.8

5.9

42 369

2.28 21.87

0.0 11.6

965.3 0.610 0.512 3.585

2.38

182.9 0.3



Confidential II Eng: IChkd: IAprvd:

I Page

150A VALVE

MIX SOUR WATER

5673 313

43

0.82

0.0

964.9 0.604 0.512 3.589

68

2.99 0.011 0. 117 3.830

8.5 182.9

0.3

!Date: n &:: 1 1 '=I /"n 1 I\

12 of 301

151 100-T-102 100-V-125

SWEET GAS

1920 337

7524.9

390.9

50 -206 2.23 1.79

100.0

4.91 0.011 0.088 5.815

5.7 886.4

0.5

IRev: n

STREAM DATA SHEETS




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/[email protected]' Flow Condition, m' /hr Flow Condition, m' /hr

Temperature , °C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Cri t Pres , Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/' C VaporMolWt Enthalpy, kJ/kg Enthalpy, MW


Temperature , °C Pseudo Cri t Temp, ' C Pressure, Mpa (g) Pseudo Gri t Pres , Mpa (a) Wt % Vaporized Liquid Deg API



151A 100-V-125

VALVE OFFGAS

1920 337

7524.9

392.1

50 -206 2.22 1.79

100.0

4.90 0.011 0.088 5.814

5.7 886.4

0.5

•Datum H20 and HG Above 15.6' C Liquid H2 Above 15.6°C Vapor


1518 152 VALVE MIX

MIX 100-V-123 OFF GAS MP/LT OIL

1920 60614 337 592

7524.9

416.5

50 55 -206 2.08 1.42 1.79

100.0 2.0

723.2 0.382 0.115 2.089

19

4.61 9.02 0.011 0.013 0.088 0.047 5.811 2.585

5.7 15.9 886.4 119.7

0.5 2.0



153 MIX

100-P-105NB QUENCH OIL

28813 137

33.7

41.4

240 428

2.39 2.26

0.0 33.6

695.2 0.237 0.076 2.652

2.49

521.9 4.2

IAprvd:

I Page 13 of 301

153A 154 100-P-105NB 100-A-104

100-A-104 SPLIT QUENCH OI L QUENCH OIL

28813 28813 137 137

33.7 33.7

39.D 36.3

243 150 428 428

18.35 18.28 2.26 2.26

0.0 0.0 33.6 33.6

739.1 793.0 0.299 0.581 0.082 0.098 2.610 2.291

542.2 314.5 4.3 2.5

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/[email protected]' Flow Condition, m'/hr Flow Condition , m' /hr








155 SPLIT SPLIT

QUENCH OIL

23143 110

27.1

29.2

150 428

18.28 2.26

0.0 33.6

793.0 0.581 0.098 2.291

314.5 2.0




MIX MIX QUENCH OIL QUENCH OIL

4999 18144 23 86

5.8 21.2

6.3 22.9

150 150 428 428

18.28 18.28 2.26 2.26

0.0 0.0 33.6 33.6

793.0 793.0 0.581 0.581 0.098 0.098 2.291 2.291

3.17 3.17

314.5 314.5 0.4 1.6



156 SPLIT

MIX QUENCH OIL

5670 27

6.6

7.2

150 428

18.28 2.26

0.0 33.6

793.0 0.581 0.098 2.291

3.17

314.5 0.5

IAprvd:

I Page 14 of 301

157 157A SPLIT VALVE

VALVE MIX MP/MT OIL MP/MT OIL

45179 45179 218 218

52.8

65.0

240 239 428

2.39 0.44 2.26

0.0 2.1 33.6

695.2 703.3 0.237 0.257 0.076 0.077 2.652 2.645

13 2.49

8.28 0.014 0.060 2.443

63.3 521.9 521.9

6.5 6.5

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS





START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/hr@ 15.6' Flow Condition, m'/hr Flow Condition , m' /hr





Temperature , °C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt % Vaporized Liquid Deg API



159 OSBL

MIX MU H2

7288 3380

75766.8

4232.3

40 -238 2.00 1.33

100.0

1.72 0.008 0.143

13.517 2.2

1573.4 3.2

160 MIX

100-ME-107 2ND STG PERM

4740 1019

22852.7

1255.5

44 -215 2.05 1.70

100.0

3.78 0.011 0.096 6.807

4.6 915.0

1.2

•Datum H20 and HG Above 15.6'C Liquid H2 Above 15.6°C Vapor



160A 100-ME-107

MIX TAIL GAS

3179 250

5604.4

4195.6

43 -138 0.06 2.91

100.0

0.76 0.012 0.050 3.054

12.7 525.2

0.5

IChkd:

161 100-ME-107

MIX PSA H2

1562 770

17255.1

979.1

43 -240 1.99 1.30

100.0

1.60 0.008 0.149

14.335 2.0

1708.3 0.7

IAprvd:

I Page 15 of 301

162 163 MIX 100-V-116

100-V-116 100-C-101 ABC H2 1ST STG SUCT

8850 8850 4149 4149

92997.6 92997.6

5242.0 5242.0

41 41 -239 -239 1.99 1.99 1.32 1.32

100.0 100.0

1.69 1.69 0.008 0.008 0.144 0.144

13.661 13.661 2.1 2.1

1597.2 1597.2 39 3.9

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS





START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/hr@ 15.6' Flow Condition, m'/hr Flow Condition , m' /hr



Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/"C VaporMolWt Entha lpy, kJ/kg Enthalpy, MW


Temperature , °C Pseudo Crit Temp, QC Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt % Vaporized Liquid Deg API



163A 100-C-101ABC 100-E-107ABC

1STSTG DSCH

8850 4149

92997.6

3199.1

133 -239 4.37 1.32

100.0

2.77 0.010 0.176

13.863 2.1

2880.5 7.1

164 100-E-107 ABC 100-V-117 ABC

COOL 1ST STG

8850 4149

92997.6

2520.5

40 -239 4.28 1.32

100.0

3.51 0.008 0.145

13.7 16 2.1

1596.0 3.9




165 100-V-117ABC 100-C-101ABC

2ND STG SUCT

8850 4149

92997.6

2527.4

40 -239 4.27 1.32

100.0

3.50 0.008 0.145

13.716 2.1

1596.0 3.9

IChkd:

166 100-C-101ABC

MIX 2NDSTG DSCH

8850 4149

92997.6

1555.4

133 -239 9.28 1.32

100.0

5.69 0.010 0.178

13.926 2.1

2898.9 7.1

IAprvd:

I Page 16 of 301

167 168 MIX 100-E-108ABC

100-E-108ABC 100-V-118ABC 2ND STG DSCH COOL 2NDSTG

30171 30171 12363 12363

277039.2 277039.2

4307.2 3631.3

103 40 -236 -236 9.27 9.20 1.37 1.37

100.0 100.0

7.00 8.31 0.010 0.009 0.158 0.139

12.325 12.22 1 2.4 2.4

2220.5 1451 .2 18.6 12.2

!Date: n &:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS






Temperature, °C Pseudo Grit Temp, ' C Pressure , Mpa (g) Pseudo Grit Pres. Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density , kg/m' Liquid Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)


END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard , Nm'/hr Flow Standard, m'/[email protected]' Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt% Vaporized Liquid Deg API




169 100-V-1 18ABC 100-C-101ABC

3RD STG SUCT

30171 12363

277039.2

3636.9

40 -236 9.18 1.37

100.0

8.30 0.009 0.139

12.221 2.4

1451.2 12.2

169A 100-C-101ABC

SPLIT RECYCLE GAS

30055 12305

275748.2

2270.4

132 -236

19.87 1.37

100.0

13.24 0.011 0.172

12.442 2.4

2629.1 22.0




1698 SPLIT OSBL

SYSTEM LEAKS

116 58

1289.7

10.6

132 -240

19.87 1.30

100.0

10.92 0.010 0.188

14.783 2.0

3112.2 0.1

IChkd:

170 SPLIT

MIX RECYCLE GAS

2935 1200

26928.0

221.9

132 -236

19.86 1.37

100.0

13.23 0.011 0.172

12.442 2.4

2629.1 2.1

IAprvd:

I Page 17 of 301

171 171A SPLIT SPLIT SPLIT MIX

RECYCLE GAS RECYCLE GAS

5424 381 2221 155

49764.0 3495.6

410.0 28.8

132 132 -236 -236

19.86 19.86 1.37 1.37

100.0 100.0

13.23 13.23 0.011 0.011 0.172 0.172

12.442 12.442 2.4 2.4

2629.1 2629.1 4.0 0.3

I Date: n~ 1 1 ~ / "') (1 1 ,.,

!Rev: n

STREAM DATA SHEETS





START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/hr@ 15.6' Flow Condition, m' /hr Flow Condition, m' /hr



Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMolWt Enthalpy, kJ/kg Entha lpy, MW





1718 SPLIT

MIX RECYCLE GAS

5040 2065

46240.9

381 .0

132 -236

19.86 1.37

100.0

13.23 0.011 0.172

12.442 2.4

2629.1 3.7

172 SPLIT

100-E-101 RECYCLE GAS

21696 8884

199056.1

1640.2

132 -236

19.86 1.37

100.0

13.23 0.011 0.172

12.442 2.4

2629.1 15.8




173 100-E-101

SPLIT RECYCLE GAS

21696 8884

199056. 1

2209.2

280 -236

19.75 1.37

100.0

9.82 0.013 0.215

12.449 2.4

4470.1 26 9

IChkd:

173A SPLIT

MIX RECYCLE GAS

1385 566

12707.1

141.1

280 -236

19.74 1.37

100.0

9.82 0.013 0.215

12.449 2.4

4470.1 1.7

IAprvd:

I Page 18 of 301

174 175 100-E-102 SPLIT

SPLIT SPLIT RECYCLE GAS RECYCLE GAS

20314 5878 8316 2408

186376.6 53929.4

2415.5 699.2

375 375 -236 -236

19.64 19.63 1.37 1.37

100.0 100.0

8.41 8.41 0.014 0.014 0.242 0.242

12.486 12.486 2.4 2.4

56539 5653.9 31 9 9.2

!Date: n &:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS










Temperature , °C Pseudo Cri t Temp, QC Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosi ty, cP Liquid K, W/mi'C Liquid Spec Heat, kJ/kg/°C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)


175A SPLIT

MIX RECYCLE GAS

881 360

8083.0

104.8

375 -236

19.63 1.37

100.0

8.41 0.014 0.242

12.486 2.4

5653.9 1.4

1758 SPLIT

MIX RECYCLE GAS

4995 2047

45828.1

594.2

375 -236

19.63 1.37

100.0

8.41 0.014 0.242

12.486 2.4

5653.9 7.8




176 SPLIT SPLIT

RECYCLE GAS

14434 5909

132428.8

1717.0

375 -236

19.63 1.37

100.0

8.41 0.014 0.242

12.486 2.4

5653 g 22.7

IChkd:

177 SPLIT SPLIT

RECYCLE GAS

8407 3441

77132.4

1000.1

375 -236

19.63 1.37

100.0

8.41 0.014 0.242

12.486 2.4

5653.9 13.2

IAprvd:

I Page 19 of 301


MIX VALVE RECYCLE GAS RECYCLE GAS

8407 6025 3441 2467

77132.4 55278.1

1017.1 716.7

375 375 -236 -236

19.28 19.63 1.37 1.37

100.0 100.0

8.27 8.41 0.014 0.014 0.242 0.242

12.485 12.486 2.4 2.4

5653 g 5653.9 13.2 9.5

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS













178A VALVE

MIX RECYCLE GAS

6025 2467

55278.1

809.9

376 -236

17.26 1.37

100.0

7.44 0.014 0.242

12.478 2.4

5653.9 9.5

179 MIX MIX

RECYCLE GAS

7792 3189

71489.9

1003.6

347 -236

17.25 1.37

100.0

7.76 0.013 0.234

12.461 2.4

5295.2 11.5




181 OSBL

MIX STRPPD WATER

22440 1246

22.5

22.8

50 374

0.60 2212

0.0 10.1

986.3 0.356 0.641 4.178

0.01

209.2 1.3

IChkd:

182 MIX

100-V-119 WATER

34942 1939

35.0

35.7

65 374

0.38 22.11

0.0 10.1

978.6 0.322 0.645 4. 183

270.8 2.6

IAprvd:

I Page 20 of 301

182A 183 100-V-119 SPLIT

SPLIT 100-P-106A/B WASH WATER WASH WATER

34942 29486 1939 1636

35.0 29.6

35.7 30.1

65 65 374 374

0.35 0.35 22.11 2211

0.0 0.0 10.1 10.1

978.6 978.6 0.322 0.322 0.645 0.645 4.183 4.183

0.03

270.8 270.8 2.6 2.2

!Date: n&:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS













184 100-P-106A/B

SPLIT HP WASH WATER

29486 1636

29.6

30.2

70 374

16.94 22.11

0.0 10.1

975.9 0.381 0.648 4.186

292.0 2.4

185 SPLIT

VALVE HP WASH WATER

24949 1383

25.0

25.6

70 374

16.94 22.11

0.0 10.1

975.9 0.381 0.648 4. 186

0.03

292.0 2.0




185A VALVE

MIX HP WASH WATER

24949 1383

25.0

25.6

70 374

IChkd:

16.25 2211

0.0 10.1

975.9 0.378 0.648 4.186

292.0 2.0

186 SPLIT

VALVE HP WASH WATER

4537 251

4.6

4.6

70 374

16.94 22.11

0.0 10.1

975.9 0.381 0.648 4. 186

0.03

292.0 0.4

IAprvd:

I Page

186A VALVE

100-T-101 HP WASH WATER

4537 251

4.6

4.6

70 374

16.11 22.11

0.0 10.1

975.9 0.377 0.648 4.186

292.0 0.4

!Date: n&:: 1 1 '=I /"n 1 I\

21 of 301

187 100-T-101 100-T-101

SOUR WATER

4617 256

4.6

4.8

60 373

16 .04 22.06

0.0 10.6

959.3 0.459 0.641 3.660

262.4 0.3

STREAM DATA SHEETS





START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/h [email protected]' Flow Condition, m' /hr Flow Condition, m' /hr

Temperature , °C Pseudo Crit Temp, 'C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt% Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMolWt Entha lpy, kJ/kg Entha lpy, MW





188 SPLIT

100-P-109NB WASH WATER

5456 303

5.5

5.6

65 374

0.35 22.11

0.0 10.1

978.6 0.322 0.645 4.183

0.03

270.8 0.4

189 100-P-109NB

VALVE MP WASH WATER

5456 303

5.5

5.6

65 374 2.52

22.11 0.0

10.1

978.3 0.330 0.645 4. 183

0.03

273.0 0.4




189A VALVE

MIX MP WASH WATER

5456 303

5.5

5.6

65 374

IChkd:

2.39 2211

0.0 10.1

978.3 0.329 0.645 4.183

273.0 0.4

190 OSBL SPLIT

LEAN AMINE

231853 8497

228.5

227.1

50 376

0.80 20.44

0.0 7.7

1021.0 2.302 0.336 3.729

170.0 10.9

IAprvd:

I Page

191 SPLIT

VALVE LEAN AMINE

179020 6561

176.4

175.3

50 376

0.80 20.44

0.0 7.7

1021 .0 2.302 0.336 3.729

0.01

170.0 8.5

!Date: n&:: 1 1 '=I /"n 1 J\

22 of 301

191A VALVE

100-E-116 LEAN AMINE

179020 6561

176.4

175.3

50 376

0.62 20.44

0.0 7.7

1021 .0 2.302 0.336 3.729

0.05

170.0 8.5

STREAM DATA SHEETS









Temperature , °C Pseudo Cri t Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt % Vaporized Liquid Deg API



1918 100-E-116 100-V-120

LEAN AMINE

179020 6561

176.4

176.0

56 376

0.41 20.44

0.0 7.7

1017.0 1.947 0.339 3.761

190.8 9.5



192 193 100-V-120 100-P-107NB

100-P-107NB VALVE LEAN AM INE HP LEAN AMINE

179020 179020 6561 6561

176.4 176.4

176.0 176.4

56 59 376 376

0.35 16.81 20.44 20.44

0.0 0.0 7.7 7.7

1017.0 1015.1 1.947 1.807 0.339 0.341 3.761 3.775

0.02 0.02

190.8 200.4 9.5 10.0



193A VALVE

100-T-101 HP LEAN AMINE

179020 6561

176.4

176.4

59 376

16.12 20.44

0.0 7.7

1015.1 1.807 0.341 3.775

200.4 10.0

IAprvd:

I Page 23 of 301

194 194A 100-T-101 LETDOWN

LETDOWN MIX RICH AMINE RICH AMINE

191363 191363 7056 7056

191.3

187.5

69 69 366

16.04 0.85 20.09

0.0 0.1 9.7

1020.5 1020.7 1.261 1.271 0.350 0.350 3.584 3.583

48 16.14

2.08 0.012 0.082 5.025

6.2 183.5 183.5

9.8 9.8

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS













195 SPLIT

100-P-108NB LEAN AMINE

52833 1937

52.1

51 .7

50 376

0.80 20.44

0.0 7.7

1021.0 2.302 0.336 3.729

0.01

170.0 2.5

195A 100-P-108NB

SPLIT LP LEAN AM INE

52833 1937

52.1

51.8

50 376 2.45

20.44 0.0 7.7

1020.7 2.271 0.337 3.732

171.6 2.5




196 SPLIT

VALVE LP LEAN AMINE

14624 535

14.4

14.3

50 376

2.45

IChkd:

20.44 0.0 7.7

1020.7 2.271 0.337 3.732

0.02

171.6 0.7

196A VALVE

100-T-102 LP LEAN AMINE

14624 535

14.4

14.3

50 376

2.31 20.44

0.0 7.7

1020.7 2.271 0.337 3.732

171.6 0.7

IAprvd:

I Page

197 100-T-102

VALVE RICH AMINE

15250 554

15.2

149

66 367

2.28 20.05

0.0 9.4

1023.4 1.393 0.344 3.559

2.38

1717 0.7

!Date: n&:: 1 1 '=I /"n 1 J\

24 of 301

197A VALVE

MIX RICH AMINE

15250 554

15.2

14.9

66 367

0.82 20.05

0.0 9.4

1023.4 1.393 0.344 3.559

171.7 0.7

STREAM DATA SHEETS




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6° Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, °C Pseudo Crit Temp, 'C Pressure, Mpa (g) Pseudo Crit Pres. Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density , kg/m' Liquid Viscosi ty. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)


END OF RUN Flow Mass, kg/h r Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/[email protected] ' Flow Condition, m' /h r Flow Condition, m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres, Mpa (a) Wt% Vaporized Liquid Deg API


Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density , kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

1978 MIX

100-V-122 RICH AMINE

206614 7610

68

0.79

0.0

1020.9 1.279 0.350 3.581

48

2.01 0.012 0.081 4.909

6.4 182.6

10.5

•Datum H20 and HC Above 15.6'C Liqu id H2 Above 15.6' C Vapor


198 198A 100-V-122 VALVE

VALVE OSBL ARU RICH AMINE RICH AMINE

206523 246251 7596 9037

206.1 245.7

202.3 241.0

68 67 367 367

0.79 0.65 20.12 20.11

0.0 0.0 9.4 9.4

1020.8 1022.0 1.280 1.329 0.350 0.348 3.582 3.573

0.89

182.2 176.9 10.5 12.1



199 MIX

100-V-121 SOUR WATER

33732 1836

53

0.79

0.3

942.5 0.484 0.413 3.619

65

4.8 1 0.013 0.082 2.228

14.5 226.6

2.1

IAprvd:

I Page 25 of 301

199A 1998 100-V-121 VALVE

VALVE OSBL SOUR WATER SOUR WATER

33640 33640 1829 1829

34.5

35.7

53 54 362

0.79 0.50 21.57

0.0 0.0 13.5

942.5 942.4 0.484 0.483 0.4 13 0.413 3.619 3.620

65 0.89

4.70 0.013 0.054 1.590

21 .0 225.3 225.3

2.1 2.1

I Date: n ~ 1 1 ~ / "') (1 1 ,.,

!Rev: n







Temperature , °C Pseudo Cri t Temp, ' C Pressure, Mpa (g) Pseudo Cri t Pres , Mpa (a) Wt % Vaporized Liquid Deg API



STREAM DATA SHEETS



199C 100-V-121

MIX SOUR GAS

92

142.1

19.1

53 -101 0.79 4.48

100.0

4.81 0.013 0.082 2.228

14.5 690.0

0





I Page 26 of 301

!Date: n&:: 1 1 '=I /"n 1 J\

IRev: n

STREAM DATA SHEETS












201 OSBL SDA 100-E-408

DAO

107849 145

108.4

117.4

170 763 1.00 1.01 0.0

10.4

918.3 13.140 0.077 2.357

321 .0 9.6



202 100-E-408

SPLIT DAO

107849 145

108.4

120.9

224 763

0.90 1.01 0.0

10.4

892.1 4.956 0.073 2.543

453.0 13.6

203 SPLIT

MIX DAO

75239 101

75.6

84.3

224 763

0.90 1.01 0.0

10.4

892.1 4.956 0.073 2.543

< 0.01

453.0 9.5



203A SPLIT

MIX DAO

32610 44

32.8

36.6

224 763

0.90 1.01 0.0

10.4

892.1 4.956 0.073 2.543

<0.01

453.0 4.1

IAprvd:

I Page

204 MIX

100-V-102 DAO

106372 162

107.3

121.5

241 737

0.36 1.12 0.0

11.0

875.5 4.173 0.072 2.586

494.0 14.6

!Date: n &:: 1 1 '=I /"n 1 I\

27 of 301

205 100-V-102

100-P-104A/B DAO

106372 162

107.3

121.5

241 737

0.35 1.12 0.0

11 .0

875.5 4.171 0.072 2.586

< 0.01

494.0 14.6

STREAM DATA SHEETS






Temperature , °C Pseudo Grit Temp, 'C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt % Vaporized Liquid Deg API







2a6 2a8 1aa-P-104A/B VALVE

VALVE MIX 2ND STG FEED 2ND STG FEED

106372 1a6372 162 162

1a7.3 1a7.3

117.5 117.6

244 245 737 737

19 .20 18.51 1.12 1.12 a.a a.o

11 .0 11.0

9a5.2 9a4.9 5.6a8 5.519 a.a81 o.a8a 2.585 2.586

< a.a1

521 .8 521.8 15.4 15.4


MAT BAL REFLECTS A a.1 % CONVERGENCE OF THE PROCESS MODEL.


2a8A MIX

1aO-H-102 2ND STG FEED

1a7253 522

249

18.49

0.7

88a.3 a.829 a.a72 2.611

18

9.40 a.a12 0.2a9

12.848 2.4

564.0 16.8

IChkd:

2a9 1aO-H-102

1aa-ME-104 FURNACE EFF

1a7253 522

373

17.30

a.8

799.5 0.261 o.a55 2.981

7

8.52 o.a 14 0.232

11 .278 2.8

919.1 27.4

IAprvd:

I Page 28 of 301

21a 211 MIX 1aO-R-103

1aO-R-103 MIX DAO RXTR FEED DAO RXTR EFF

11225a 112252 257a 2194

373 443

17.23 16.84

6.0 35.5

9aa.1 692.5 a.263 a.129 a.a55 a.a53 2.982 3.178

7 a

8.63 54.87 o.a15 a.a25 0.231 a.218

11 .129 3.888 2.8 20.7

1129.9 1364.a 35.2 42.5

!Date: n&:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS












Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMolWt Enthalpy, kJ/kg Enthalpy. MW

212 MIX MIX

DAO RXTR EFF

115187 3397

415

16.84

37.9

693.3 0.142 0.052 3.100

0

38.31 0.023 0.210 4.381

13.9 1396.2

44 .7

212A MIX

100-V-106 DAO RXTR EFF

120857 3423

405

16.82

36.1

689.9 0.142 0.053 3.079

0

38.87 0.023 0.205 4.356

13.9 1345.5

45.2




213 100-V-106

MIX HP/HTVAP

43674 3144

70475.8

1123.6

405 -181

16.82 1.77

100.0

38.87 0.023 0.205 4.356

13.9 1965.1

23.8

IChkd:

214 100-V-106

LETDOWN HP/HT LIQ

77185 279

84.1

111.9

405 367

16.82 1.78 0.0

22.4

689.9 0.142 0.053 3.079

16.92

994.9 21.3

IAprvd:

I Page 29 of 301

215 216 LETDOWN 100-V-107 100-V-107 MIX HP/HT LIQ MP/HTVAP

77185 3840 279 83

1921 .0

173.7

408 408 -65

2.72 2.69 211

4 9 100.0

684.3 0.190 0.054 3.092

7

22.19 22.11 0.022 0.022 0.181 0.181 3.197 3.194 44 .5 44.8

994 9 1389.8 21.3 1.5

!Date: n&:: 1 1 '=I /"n 1 J\






END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m3/[email protected]' Flow Condition, m'/hr Flow Condition, m' /hr




STREAM DATA SHEETS



217 100-V-107

LETDOWN MP/HT LIQ

73345 191

77.7

107.1

408 558 2.69 1.64 0.0

18.2

684.5 0.190 0.054 3092

2.79

974.2 19.9


218 LETDOWN 100-T-303

MP/HT OIL

73345 191

405

0.38

6.7

710.2 0.278 0.057 3.076

10

13.17 0.015 0.075 2.839 147.0 974.2

19.9




I Page 30 of 301

!Date: n&:: 1 1 '=I /"n 1 J\

IRev: n

3.0 - 1

3.0 - FRACTIONATION SECTION

3 .1 Process Description

3 .1.1 Introduction

The following is a description of the fractionation section scheme as depicted on the Process Flow Diagrams BF-133111 through BF-133115. The fractionation section is comprised of the Atmospheric Tower, Vacuum Tower, Atmospheric Stripper, Vacuum Stripper and Sour Gas Compressor. The Atmospheric Tower is designed to separate the reactor effluent into sour gas, wild naphtha, diesel, and Atmospheric Tower bottoms. The Vacuum Tower is designed to separate the Atmospheric Tower bottoms and Vacuum Stripper products into non condensable vapor, slop oil, LLVGO, LVGO, HVGO and Vacuum Tower bottoms. Sour gas from the Atmospheric Tower overhead is compressed in the Sour Gas Compressor and sent to the light ends recovery section with the wild naphtha.

3 .1.2 Atmospheric Tower and Atmospheric Stripper

The VR MP/HT oil (which contains most of the residue range material) is sent directly to the bottom section of the Atmospheric Tower, where it is flashed and stripped with superheated LP steam in order to reduce the tower bottoms H2S content to below 10 wt. ppm. The LT and MT oil, after preheating, are sent to the LT/MT Oil Surge Drum (100-V-301). The vapor from 100-V-301 is sent directly to the Atmospheric Tower while the liquid is pumped by the Atmospheric Tower Feed Pumps (100-P-301A/B) and fed to the Atmospheric Tower Feed Furnace (100-H-301) . Each of the furnace passes is on flow control reset by level in 1 OO-V-301.

The vapors above the flash zone are first contacted with pumparound and then with reflux liquid recovered from the Atmospheric Tower Reflux Drum (100-V-302) .

The tower overhead is condensed in two steps to control the chloride related corrosion in the tower. First it is partially condensed to an intermediate wmm temperature ( 108°C) with variable speed air cooler (Atmospheric Tower Reflux Air Cooler, 100-A-301) prior to entering the Atmospheric Tower Reflux Drum (100-V-302) . The condensed wmm hydrocarbon liquid is returned to the tower as reflux on flow control reset by level.

The uncondensed vapor from 100-V-302 is further cooled by the Atmospheric Tower Overhead Product Air Cooler (1 OO-A-302), with the resulting mixture separated in the Atmospheric Tower Overhead Product Drnm (100-V-303) . The hydrocarbon liquid from 100-V-303 is then pumped and sent to the light ends recovery section on flow control reset by level. The sour vapor is compressed by the sour gas compressor m1d sent to the light ends recovery section.

The Atmospheric Tower has a single diesel product draw and pumparound (PA). The diesel is taken as a total draw from the column, and split between the Diesel Stripper (1 OO-T-302), and Atmospheric Tower PA Pumps (100-P-304 A/B) . The discharge of the pumps is in turn split into the wash liquid, which is returned to the Atmospheric Tower on flow control. and the PA. The PA


TO BE REPRODUCED, AN D USED, ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF


3.0 - 2

provides heat for the Naptha Stabilizer Reboiler (lOO-E-504), the Deethanizer Reboiler (100-E-503) and the Atmospheric Tower feed (100-E-302) before returning to the tower. The diesel fed to l OO-T-302 is stripped with superheated LP Steam and then cooled via heat exchange with the Atmospheric Tower feed, air cooling, and water cooling in the LT Oil/Diesel Exchanger (100-E-301), the Diesel Product Air Cooler (100-A-303), and the Diesel Product Trim Cooler (100-E-304) respectively before being sent OSBL.

The DAO MP/HT oil is sent directly to the Atmospheric Stripper where it is flashed and stripped with super-heated low pressure steam to remove the majority of hydrogen sulphide. The Atmospheric Stripper overhead vapor product is routed to the Atmospheric Tower where it combines with the vapor from l OO-V-301.

3 .1.3 Sour Gas Compressor

The sour gas from the Atmospheric Tower Overhead Product Drum (100-V-303) is mixed with the tail gas from the PSA Unit and fed to the Sour Gas Compressor l st Stage Suction Drum (1 OO-V-304 ), where any entrained or condensed liquid is separated and sent to flare. A high setpoint pressure controller to flare is provided in case of high suction pressure. Vapor from l OO-V-304 is sent to the Sour Gas Compressor (100-C-301A/B), a two stage centrifogal compressor, where it is compressed to the Deethanizer overhead pressure. After the first stage of compression, the sour gas is cooled by air in the Sour Gas Compressor Discharge Cooler (100-A-304). Condensed liquid is then separated on level control in the Sour Gas Compressor Discharge KO Drum (100-V-305) and returned to 100-V-303. Sour gas is compressed in the second stage of 100-C-301 and sent to the light ends recovery section. Individual stage spillback valves are provided to protect against damage to the compressor due to high differential stage pressure. The compressor is equipped with a capacity control and anti-surge system that maintains the suction pressure of the first stage and thus the overhead pressure in the Atmospheric Tower.

3 .1.4 Vacuum Tower and Vacuum Stripper

Atmospheric Stripper bottoms is fed to the Vacuum Stripper (l OO-T-402), which is stripped with superheated LP steam. The Vacuum Stripper bottoms is pumped by the Vacuum Stripper Bottoms pump and split into DAO recycle and feed to the Vacuum Tower Feed Furnace (100-H-401). The latter is mixed with the Atmospheric Tower bottoms and velocity steam, let down to vacuum conditions, and partially vaporized in the Vacuum Tower Feed Furnace (100-H-401) . The Vacuum Tower feed temperature is controlled by adjusting the furnace firing.

The furnace effluent and the Vacuum Stripper overhead are both fed to the Vacuum Tower ( l OO-T-401) for recove1y of vacuum gas oil (VGO).

The partially vaporized feed is separated in the flash zone of l OO-T-401. The disengaged liquid is stripped with superheated LP steam to produce Vacuum Tower bottoms product free of lighter end components. The disengaged feed vapor plus the vapor from the bottom stripping section are combined and flow up through the packed two stage wash section. The purpose of the wash section is to minimize entrainment of heavy liquid and metals in the vacuum gas oil sidecut




3.0 - 3

products. The first wash zone, the bottommost bed immediately above the flash zone, uses a continuously recirculated stream of very heavy vacuum gas oil. This wash consists of a total draw which is pumped by 100-P-406 A/B and split into the flow controlled recirculating wash and a level controlled feed back to the flash zone. The second, or upper wash zone, uses flow controlled hot condensed heavy vacuum gas oil (HVGO) as the wash liquid.

Three trim circulating refluxes and three total liquid draws are taken from above the wash section. In the bottom circulating reflux, an HVGO product is withdrawn. Part of this stream is pumped by the HVGO Pumps (100-P-405A/B) back to the upper wash zone, as described above. The remainder is cooled by preheating VR feed in the HVGO/Feed Exchanger (100-E-406) and by generating LP steam in the HVGO Steam Generator (100-E-404). A portion of the draw upstream of 1 OO-E-404 is split off and circulated to the DAO Feed Surge Drum. The temperature of the HVGO PA is controlled by a bypass around the steam generator. At this point, part of the circulating reflux is returned to the tower on flow control while the balance is mixed with the L VGO cut from the tower, air cooled by the VGO Air Cooler (1 OO-A-402) and sent OSBL as VGO product. The HVGO level on the draw tray in the column is controlled by resetting the HVGO product flow controller.

In the middle circulating reflux, light vacuum gas oil (L VGO) product is \vithdrawn. Part of this stream is pumped by the LVGO Pumps (100-P-404A/B) and mixed with HVGO pumparound returning to the Vacuum Tower. The L VGO circulating reflux mid product is cooled by preheating VR feed in the L VGO/F eed Exchanger (1 OO-E-405) and by generating LLP steam in the L VGO Steam Generator (1 OO-E-403). The temperature of the L VGO PA is controlled by bypasses around 100-E-405 and 100-E-403. After having been cooled in 100-E-405 and 100-E-403, the LVGO is split into three separates streams. The first stream is mixed with HVGO, cooled, and sent OSBL as VGO product. The second stream is sent to the Atmospheric Tower and Atmospheric Stripper as quench. The third stream is returned to the tower on flow control as circulating reflux.

In the top circulating reflux, LL VGO product is withdrawn. Part of this stream is pumped by the LLVGO Pumps (100-P-408A/B) back to the LVGO PA bed below. The LLVGO circulating reflux and product is air cooled by a temperature controlled variable speed air cooler, the Top Reflux Air Cooler (100-A-401). At this point, the circulating reflux is sent to the top bed on flow control and the product is sent to OSBL on flow control reset by the level controller on the LL VGO draw tray after being cooled by the LL VGO Water Cooler ( 1 OO-E-402).

Strainers are provided for the HVGO and heavier streams returned to the tower to prevent plugging of the holes of the liquid distributors. The wash oil and Vacuum Tower Bottoms Pumps (1 OO-P-407 A/B) are provided with suction strainers due to the high coking nature of these services. A coke catcher is installed in the bottom of the Vacuum Tower and Vacuum Stripper.

The Vacuum Tower overhead vapor is cooled in the 3-stage Vacuum Tower Ejector System (100-ME-401) condensing most of the water vapor and condensable hydrocarbons. The condensables from the ejectors flow to the Vacuum Tower Hotwell (100-V-401), where the hydrocarbon liquid is separated from the steam condensate. The hydrocarbon is sent to slop,




3.0 - 4

while the sour water is sent OSBL. The noncondensable vapor is sent to the Hotwell Vapor Water Seal Dmm (100-V-402) and finally OSBL. There is a pressure controller on the 3-stage condenser outlet spillback to maintain suction pressure of the ejector system and both the hydrocarbon and sour water are flow controlled reset by the hotwell level.

The Vacuum Tower bottoms are pumped by the Vacuum Tower Bottoms Pumps to the off plot SDA Unit via a rundown cooling circuit consisting of the Vacuum Tower BottomsNR Feed Exchanger (100-E-407), and Vacuum Tower Bottoms/DAO Feed Exchanger (100-E-408). The Vacuum Tower bottom stream is the feed to the SDA unit where asphaltenes from the vacuum tower bottoms are removed via extraction with solvent.

There is a provision to route a portion of the cooled Vacuum Tower bottoms stream back to the bottom of the Vacuum Tower on flow control to quench the tower bottoms, if required.






TO BE REPRODUCED AND USED ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF


0 0

,-------------------

t'l<~ .,;;;g

~----- !~ii_ _______ _

' _____ J

,

l --,

LJ

0 0

' -------------~

C------1-~I 1~

r-i ~ _ _J

0 0

3.3 Stream Data

This section contains the fractionation section stream data and component balances for normal operating conditions . Included are component balance sheets showing detailed component breakdown and stream data sheets showing flow rates and physical properties for each stream.


TO BE REPRODUCED. AND USED, ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF


COMPONENT SUMMARY

FRACTIONATION SECTION



START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'ihr @1 Total Vap. Std. Flow, Nm'ihr


300 100-E-112AIB

100-V-301 ATM TWR FEED

17 1025

5 22 85

361 1163 930

1108 0 0

28385 59746 11600

147 0

0 104594

735


301 302 100-V-301 100-V-301 100-T-301 100-P-301 AIB

LT/MT VAPOR LT/MT OIL

17 0 994 31

5 0 21 0 84 1

352 9 1119 44 876 54

1038 70 0 0 0 0

20560 7825 12219 47526

29 11571 0 147 0 0

0 0 37314 67278

387 348 79.9

8676.9



I Eng:

303 100-P-301AIB

VALVE LT/MT OIL

0 31 0 0 1 9

44 54 70

0 0

7825 47526 11571

147 0

0 67278

348 79.9

IAprvd:

I Page 1 of 2sl

304 305 VALVE 100-H-301

100-H-301 TRANSFER LINE FURNACE FEED A TM TWR FEED

0 31

0 0 1 9

44 54 70

0 0

7825 47526 11571

147 0

0 67278

348 79.9

I Date: 06/13/2014

0 31

0 0 1 9

44 54 70

0 0

7825 47526 11571

147 0

0 67278

348




COMPONENT SUMMARY




I Page

306 308 309 313 314 315 TRANSFER LINE HEADER VALVE HEADER VALVE SPLIT

100-T-301 VALVE 100-T-301 VALVE 100-T-302 100-T-302 ATM TWR FEEDSTRPPNG STEAMSTRPPNG STEAMSTRPPNG STEAMSTRPPNG STEAM ATM TOWER PA

0 0 0 0 0 0 31 0 0 0 0 13

0 0 0 0 0 0 0 7901 7901 3500 3500 82 1 0 0 0 0 0 9 0 0 0 0 3

44 0 0 0 0 17 54 0 0 0 0 20 70 0 0 0 0 26

0 0 0 0 0 0 0 0 0 0 0 0

7825 0 0 0 0 8105 47526 0 0 0 0 124060 11571 0 0 0 0 666

147 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 67278 7901 7901 3500 3500 132992

348 439 439 194 194 731 159.7

9830.3 9830.3 4354.6 4354.6



I Eng: IAprvd: I Date: 06/13/2014

COMPONENT SUMMARY FRACTIONATION SECTION





316 100-T-302 100-T-301

DSL STRP OVHD

0 13 0

3362 0 3

17 20 26

0 0

6405 23682

4 0 0

0 33532

387

8735.7


317 318 100-T-301 SPLIT

SPLIT 1 OO-P-304A/B ATM TOWER PA ATM TOWER PA

0 0 48 35

0 0 309 226

1 1 13 10 63 46 77 57 99 73

0 0 0 0

30417 22312 465588 341529

2499 1833 0 0 0 0

0 0 499114 366122

2746 2015 599.2 439.5



I Eng:

319 SPLIT

100-T-301 PUMPBACK

0 7 0

47 0 2

10 12 15 0 0

4662 71360

383 0 0

0 76498

421 91 .8

IAprvd:

I Page 3 of 2sl

320 321 1 OO-P-304A/B SPLIT

SPLIT 100-E-504 ATM TOWER PA ATM TOWER PA

0 35

0 226

1 10 46 57 73

0 0

22312 341529

1833 0 0

0 366122

2015 439.5

I Date: 06/13/2014

0 28

0 179

1 7

36 45 58

0 0

17650 270169

1450 0 0

0 289623

1595 347.7

COMPONENT SUMMARY






322 1 OO-E-504 1 OO-E-503

ATM TOWER PA

0 28

0 179

1 7

36 45 58

0 0

17650 270169

1450 0 0

0 289623

1595 347.7


323 324 100-E-503 100-E-302 100-E-302 VALVE

ATM TOWER PA ATM TOWER PA

0 0 28 28

0 0 179 179

1 1 7 7

36 36 45 45 58 58

0 0 0 0

17650 17650 270169 270169

1450 1450 0 0 0 0

0 0 289623 289623

1595 1595 347.7 347.7



I Eng:

324A VALVE

100-T-301 ATM TOWER PA

0 28

0 179

1 7

36 45 58 0 0

17650 270169

1450 0 0

0 289623

1595 347.7

IAprvd:

I Page 4 of 2sl

337 338 100-T-301 100-A-301 100-A-301 100-V-302

ATM TWROVHD ATM TWR RFLX

76 1275

15 12951

130 429

1343 1116 1354

0 0

140475 21091

0 0 0

0 180255

2262

50741.4

I Date: 06/13/2014

76 1329

44 38452

131 429

1343 1116 1354

0 0

140477 21089

0 0 0

0 205840

3681

COMPONENT SUMMARY






339 1 OO-V-302

1 0 O-P-302A/B ATM TWR RFLX

0 49

1 277

1 12 83

125 180

0 0

110313 19739

0 0 0

0 130780

1101 174.9


340 340A 1 OO-P-302A/B VALVE

VALVE 100-T-301 ATM TWR RFLX ATM TWR RFLX

0 0 49 49

1 1 277 277

1 1 12 12 83 83

125 125 180 180

0 0 0 0

110313 110313 19739 19739

0 0 0 0 0 0

0 0 130780 130780

1101 1101 174.9 174.9



I Eng:

341 100-V-302

1 OO-P-307 A/B ATMTWR

0 14 11

26991 0 0 0 0 0 0 0 0 0 0 0 0

0 27016

1498 27.1

IAprvd:

I Page

341A 1 OO-P-307 A/B

VALVE ATMTWR

0 14 11

26991 0 0 0 0 0 0 0 0 0 0 0 0

0 27016

1498 27.1

I Date: 06/13/2014

5 of 2sl

341B VALVE

MIX ATMTWR

0 14 11

26991 0 0 0 0 0 0 0 0 0 0 0 0

0 27016

1498 27.1

COMPONENT SUMMARY




Stream No 342 343 From 100-V-302 100-A-302 To 100-A-302 MIX Content RLX DRUM VAP RFLX DRUM VAP



76 76 1267 1267

32 32 11184 11184

129 129 417 417

1259 1259 991 991

1174 1174 0 0 0 0

30164 30164 1350 1350

0 0 0 0 0 0

0 0 48043 48043

1083 1083

24241 .6



I Eng:

343A MIX

100-V-303 RFLX DRUM VAP

76 1267

32 11214

129 417

1260 992

1175 0 0

30203 1352

0 0 0

0 48117

1084

344 100-V-303

1 OO-P-308A/B ATMTWR

0 68 31

10971 0 0 0 0 0 0 0 0 0 0 0 0

0 11070

613 11 .1

IAprvd:

I Page

345 1 OO-P-308A/B

VALVE ATMTWR

0 68 31

10971 0 0 0 0 0 0 0 0 0 0 0 0

0 11070

613 11 .1

I Date: 06/13/2014

6 of 2sl

345A VALVE

MIX ATMTWR

0 68 31

10971 0 0 0 0 0 0 0 0 0 0 0 0

0 11070

613 11 .1







346 346A 347 348 MIX SPLIT 100-V-303 1 OO-P-303A/B

SPLIT MIX 1 OO-P-303A/B VALVE ATMTWR ATMTWR WILD NAPHTHA WILD NAPHTHA

0 0 0 0 82 27 95 95 42 14 0 0

37963 12461 13 13 0 0 2 2 0 0 23 23 0 0 190 190 0 0 295 295 0 0 425 425 0 0 0 0 0 0 0 0 0 0 28139 28139 0 0 1346 1346 0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 38087 12502 30528 30528

2111 694 295 295 38.2 12.5 42.2 42.2



I Eng: IAprvd:

I Page

349 VALVE

MIX WILD NAPHTHA

0 95

0 13 2

23 190 295 425

0 0

28139 1346

0 0 0

0 30528

295 42.2

I Date: 06/13/2014

7 of 2sl

350 100-V-303

MIX OVHD VAPOR

76 1104

1 229 127 393

1070 696 750

0 0

2064 6 0 0 0

0 6516

177

3954.4




COMPONENT SUMMARY




350A 351 353 354 MIX 100-V-304 100-C-301 100-A-304

100-V-304 100-C-301 100-A-304 100-V-305 SOUR GAS SOUR GAS SOUR GAS SOUR GAS

349 349 349 349 1105 1105 1105 1105

1 1 1 1 264 264 264 264

1285 1285 1285 1285 961 961 961 961

1602 1602 1602 1602 892 892 892 892 919 919 919 919

0 0 0 0 0 0 0 0

2307 2307 2307 2307 9 9 9 9 0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 9694 9694 9694 9694 426 426 426 426

9556.3 9556.3 9556.3



I Eng: IAprvd:

I Page B of 2sl

355 356 100-V-305 100-C-301 100-C-301 MIX

SOUR GAS 2ND STG DSCH

349 1105

1 234

1285 961

1602 892 919

0 0

2267 6 0 0 0

0 9621 424

9510.3

I Date: 06/13/2014

349 1105

1 234

1285 961

1602 892 919

0 0

2267 6 0 0 0

0 9621 424

9510 .3




Stream No 362 363 From 100-V-305 VALVE To VALVE MIX Content CONDENSED LIQ CONDENSED LIQ



0 0 0

30 0 0 0 0 1 0 0

40 2 0 0 0

0 73

2 0.1



I Eng:

0 0 0

30 0 0 0 0 1 0 0

40 2 0 0 0

0 73 2

370 100-T-302

1 OO-P-305A/B DIESEL

0 0 0

220 0 0 0 0 0 0 0

1700 100378

662 0 0

0 102960

536 121 .7

371 1 OO-P-305A/B 100-E-301A/B

DIESEL

0 0 0

220 0 0 0 0 0 0 0

1700 100378

662 0 0

0 102960

536 121 .7

IAprvd:

I Page

373 100-E-301A/B

100-A-303 DIESEL

0 0 0

220 0 0 0 0 0 0 0

1700 100378

662 0 0

0 102960

536 121 .7

I Date: 06/13/2014

9 of 2sl

374 100-A-303 100-E-304

DIESEL

0 0 0

220 0 0 0 0 0 0 0

1700 100378

662 0 0

0 102960

536 121 .7




COMPONENT SUMMARY




375 375A 376 377 1 OO-E-304 VALVE 100-T-301 1 OO-P-306A/B

VALVE OSBL 1 OO-P-306A/B VALVE DIESEL DIESEL ATM TWR BTTMS ATM TWR BTTMS

0 0 0 0 0 0 0 0 0 0 0 0

220 220 114 114 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

1700 1700 1 1 100378 100378 15906 15906

662 662 141855 141855 0 0 103015 103015 0 0 0 0

0 0 0 0 102960 102960 260891 260891

536 536 554 554 121.7 121 .7 270.1 270.1



I Eng: IAprvd:

I Page 10 of 2sl

380 381 100-T-303 100-T-303 100-T-301 VALVE

ATM STRP VAP ATM STRP BTMS

15 20

2 1577

10 12 22 15 16

0 0

710 11792 6084

37 0

0 20312

174

3954.2

I Date: 06/13/2014

0 0 0

25 0 0 0 0 0 0 0 0

2675 38858 23807

0

0 65365

139 67.8




COMPONENT SUMMARY




382 383 384 385 1 OO-V-123 VALVE 100-E-302 100-E-301A/B

VALVE 100-E-302 100-E-301 A/B MIX LTOIL LTOIL LTOIL LTOIL

7 7 7 7 947 947 947 947

0 0 0 0 15 15 15 15 73 73 73 73

340 340 340 340 1118 1118 1118 1118 897 897 897 897

1070 1070 1070 1070 0 0 0 0 0 0 0 0

25258 25258 25258 25258 29261 29261 29261 29261

428 428 428 428 0 0 0 0 0 0 0 0

0 0 0 0 59414 59414 59414 59414

515 515 515 515 78.9



I Eng: IAprvd:

I Page

386 MIX

100-E-112A/B ATM FEED

17 1025

5 22 85

361 1163 930

1108 0 0

28385 59746 11600

147 0

0 104594

735

I Date: 06/13/2014

11 of 2sl

392 HEADER

VALVE STRPPNG

0 0 0

1600 0 0 0 0 0 0 0 0 0 0 0 0

0 1600

89

1990.7

COMPONENT SUMMARY






393 VALVE

100-T-303 STRPPNG STEAM

0 0 0

1600 0 0 0 0 0 0 0 0 0 0 0 0

0 1600

89

1990.7


396 396A SPLIT VALVE

VALVE MIX ATMTWR ATMTWR

0 0 55 55 29 29

25501 25501 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

0 0 25585 25585

1420 1420 25 .7



I Eng: IAprvd:

I Page 12 of 2sl

I Date: 06/13/2014




COMPONENT SUMMARY

VACUUM SECTION



401 402 403 404 OSBL MIX 100-ME-401 100-ME-401

MIX 100-ME-401 OSBL OSBL AIR LEAK VAC TWR OVHD NONCOND'ABLE VACTWR SLOP

0 1 1 0 0 89 88 0 0 0 0 0 0 16825 36 0 0 50 50 0 0 36 36 0 0 47 47 0 0 0 0 0 0 94 93 1

17 17 17 0 5 5 5 0 0 1 0 0 0 498 2 497 0 8 0 8 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

22 17671 375 506 947 13 2

0.6 17.1 21231.7



I Eng: IAprvd:

I Page

405 100-ME-401

OSBL SOUR WATER

0 0 0

59600 0 0 0 0 0 0 0 0 0 0 0 0 0 0

59600 3308 59.7

I Date: 06/13/2014

13 of 2sl

406 HEADER

MIX COIL STEAM

0 0 0

4990 0 0 0 0 0 0 0 0 0 0 0 0 0 0

4990 277

6208 .5

COMPONENT SUMMARY

VACUUM SECTION





415 MIX MIX

FURNACE FEED

0 0 0

115 0 0 0 0 0 0 0 1

15910 147720 114150

0 0 0

277896 581

287.1


419 421 100-H-401 100-T-401

MIX 1 OO-P-408A/B FURNACE EFF LLVGO

1 0 89 0

0 0 5104 3

50 0 36 0 47 0

0 0 94 0

0 0 0 0 1 0

15879 155289 147434 78633 114150 0

0 0 0 0 0 0

282885 233925 868 828

261.5



I Eng:

422 1 OO-P-408A/B

SPLIT LLVGO

0 0 0 3 0 0 0 0 0 0 0 0

155289 78633

0 0 0 0

233925 828

261.5

IAprvd:

I Page

423 SPLIT

100-A-401 LLVGO

0 0 0 2 0 0 0 0 0 0 0 0

111 327 56372

0 0 0 0

167701 592

187.5

I Date: 06/13/2014

14 of 2sl

424 100-A-401

SPLIT LLVGO

0 0 0 2 0 0 0 0 0 0 0 0

111327 56372

0 0 0 0

167701 592

187.5



END OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kg/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr@1 Total Yap. Std. Flow, Nm'/hr

COMPONENT SUMMARY

VACUUM SECTION



425 425A 425B SPLIT 100-E-402 VALVE

1 OO-E-402 VALVE OSBL LLVGO LLVGO LLVGO

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

7892 7892 7892 3996 3996 3996

0 0 0 0 0 0 0 0 0 0 0 0

11888 11888 11888 42 42 42

13.3 13.3 13.3


426 SPLIT

VALVE LLVGO

0 0 0 1 0 0 0 0 0 0 0 0

43961 22260

0 0 0 0

66222 234 74.0


I Eng: IAprvd:

I Page

426A VALVE

MIX LLVGO

0 0 0 1 0 0 0 0 0 0 0 0

43961 22260

0 0 0 0

66222 234 74.0

I Date: 06/13/2014

15 of 2sl

426B MIX

100-T-401 LVGO

0 0 0 3 0 0 0 0 0 0 0 0

73132 219883

0 0 0 0

293018 906

323.5




COMPONENT SUMMARY VACUUM SECTION



427 428 431 432 SPLIT VALVE 100-T-401 1 OO-P-404A/B

VALVE 100-T-401 1 OO-P-404A/B SPLIT LLVGO LLVGO LVGO LVGO

0 0 0 0 0 0 0 0 0 0 0 0 2 2 3 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

103436 103436 48965 48965 52376 52376 331723 331723

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

155814 155814 380691 380691 551 551 1128 1128

174.2 174.2 418.8 418.8



I Eng: IAprvd:

I Page

433 SPLIT

VALVE LVGO

0 0 0 0 0 0 0 0 0 0 0 0

10135 68664

0 0 0 0

78799 234 86.7

I Date: 06/13/2014

16 of 2sl

433A VALVE

MIX LVGO

0 0 0 0 0 0 0 0 0 0 0 0

10135 68664

0 0 0 0

78799 234 86.7




COMPONENT SUMMARY

VACUUM SECTION



435 436 437 SPLIT 100-E-405 100-E-403

1 OO-E-405 100-E-403 SPLIT LVGO LVGO LVGO

0 0 0 0 0 0 0 0 0 2 2 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

38830 38830 38830 263059 263059 263059

0 0 0 0 0 0 0 0 0 0 0 0

301891 301891 301891 894 894 894

332.1 332 .1 332.1


438 SPLIT

MIX LVGO

0 0 0 0 0 0 0 0 0 0 0 0

4641 31441

0 0 0 0

36082 107

39.7


I Eng: IAprvd:

I Page

439 SPLIT SPLIT LVGO

0 0 0 2 0 0 0 0 0 0 0 0

34188 231617

0 0 0 0

265807 788

292.4

I Date: 06/13/2014

17 of 2sl

439A SPLIT

VALVE LVGO

0 0 0 2 0 0 0 0 0 0 0 0

29171 197622

0 0 0 0

226795 672

249.5




COMPONENT SUMMARY

VACUUM SECTION



4398 440 441 442 VALVE SPLIT SPLIT SPLIT

MIX SPLIT 100-T-301 100-T-303 LVGO LVGO LVGO QUENCH LVGO QUENCH

0 0 0 0 0 0 0 0 0 0 0 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

29171 5018 3595 1364 197622 33995 24688 9365

0 0 0 0 0 0 0 0 0 0 0 0 0 0

226795 39013 28283 10729 672 116 84 32

249.5 42 .9 31 .1 11 .8



I Eng: IAprvd:

I Page

443 100-T-401

100-P-405A/B HVGO

0 0 0 3 0 0 0 0 0 0 0 0

2918 487343

229 0 0 0

490493 1212

524.5

I Date: 06/13/2014

18 of 2sl

444 1 OO-P-405A/B

SPLIT HVGO

0 0 0 3 0 0 0 0 0 0 0 0

2918 487343

229 0 0 0

490493 1212

524.5


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ YR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr @1 Total Yap. Std. Flow, Nm'/hr


COMPONENT SUMMARY

VACUUM SECTION



445 445A 447 448 SPLIT 100-G-403A/B SPLIT 100-E-406

1 OO-G-403A/B 100-T-401 100-E-406 SPLIT HVGO HVGO HVGO HYGO

0 0 0 0 0 0 0 0 0 0 0 0 1 1 2 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

795 795 2123 2123 132781 132781 354561 354561

62 62 166 166 0 0 0 0 0 0 0 0 0 0 0 0

133639 133639 356852 356852 330 330 883 883

142.9 142.9 381.6 381.6



I Eng: IAprvd:

I Page

448A SPLIT

100-E-404 HYGO

0 0 0 2 0 0 0 0 0 0 0 0

2050 342321

161 0 0 0

344534 852

368.4

I Date: 06/13/2014

19 of 2sl

449 100-E-404

SPLIT HYGO

0 0 0 2 0 0 0 0 0 0 0 0

2050 342321

161 0 0 0

344534 852

368.4




COMPONENT SUMMARY

VACUUM SECTION



450 451 452 SPLIT MIX SPLIT

MIX 100-T-401 VALVE HVGO HVGO HVGO

0 0 0 0 0 0 0 0 0 1 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

1619 11755 430 270406 339071 71914

127 127 34 0 0 0 0 0 0 0 0 0

272153 350955 72378 673 907 178

291.0 377.7 77.4


452A VALVE

MIX HVGO

0 0 0 0 0 0 0 0 0 0 0 0

430 71914

34 0 0 0

72378 178

77.4


I Eng: IAprvd:

I Page

453 MIX

100-A-402 VGO

0 0 0 1 0 0 0 0 0 0 0 0

5072 103356

34 0 0 0

108463 286

117.1

I Date: 06/13/2014

20 of 2sl

454 100-A-402

OSBL VGO

0 0 0 1 0 0 0 0 0 0 0 0

5072 103356

34 0 0 0

108463 286

117.1




COMPONENT SUMMARY

VACUUM SECTION



455 456 457 458 100-T-401 1 OO-P-406A/B SPLIT 1 OO-G-402A/B

1 OO-P-406A/B SPLIT 1 OO-G-402A/B 100-T-401 WASH OIL WASH OIL WASH OIL WASH OIL

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

117 117 54 54 51891 51891 23984 23984 17667 17667 8166 8166

0 0 0 0 0 0 0 0 0 0 0 0

69675 69675 32204 32204 141 141 65 65

71 .6 71 .6 33.1 33.1



I Eng: IAprvd:

I Page

459 SPLIT

VALVE WASH OIL

0 0 0 0 0 0 0 0 0 0 0 0

63 27906

9501 0 0 0

37470 75

38.5

I Date: 06/13/2014

21 of 2sl

459A VALVE

100-T-401 WASH OIL

0 0 0 0 0 0 0 0 0 0 0 0

63 27906

9501 0 0 0

37470 75

38.5

COMPONENT SUMMARY

VACUUM SECTION





460 100-T-401

100-P-407 A/B VAC TWR BTMS

0 0 0 1 0 0 0 0 0 0 0 0 0

20342 114460

0 0 0

134803 179

131.5


461 462 1 OO-P-407 A/B 100-E-407

100-E-407 100-E-408 VACTWR BTMS VACTWR BTMS

0 0 0 0 0 0 1 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

20342 20342 114460 114460

0 0 0 0 0 0

134803 134803 179 179

131 .5 131 .5



I Eng:

462A 100-E-408

SPLIT VACTWR BTMS

0 0 0 1 0 0 0 0 0 0 0 0 0

20342 114460

0 0 0

134803 179

131 .5

IAprvd:

I Page

463 100-E-408

OSBLSDA VACTWR BTMS

0 0 0 1 0 0 0 0 0 0 0 0 0

20342 114460

0 0 0

134803 179

131 .5

I Date: 06/13/2014

22 of 2sl

467 SPLIT

MIX HVGO

0 0 0 0 0 0 0 0 0 0 0 0

73 12241

6 0 0 0

12320 30

13.2

Stream No From

COMPONENT SUMMARY

VACUUM SECTION



I Page 23 of 2sl

469 4 70 480 480A 481 482 HEADER VALVE VALVE MIX 100-T-402 100-T-402

VALVE 100-T-401 MIX 100-T-402 MIX 100-P-401A/B To Content STRPPNG STEAMSTRPPNG STEAM ATM STRP BTMS VAC STRP FEED VAC STRP OVHD VAC STRP BTMS



0 0 0 0 0 0

4870 4870 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

4870 4870 270 270

6059.2 6059.2



I Eng:

0 0 0 0 0 0

25 5804 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

2675 2675 38858 38858 23807 23807

0 0

0 0 65365 71144

139 460

IAprvd:

0 0 0

6853 0 0 0 0 0 0 0 0

2674 26504

350 0

0 36381

462

10343.3

I Date: 06/13/2014

0 0 0 1 0 0 0 0 0 0 0 0 0

12354 23457

0

0 35812

55 35.8

COMPONENT SUMMARY I Page VACUUM SECTION



Stream No 483 484 485 486 487 From 100-P-401AIB SPLIT VALVE SPLIT VALVE To SPLIT VALVE MIX VALVE MIX Content VAC STRP BTMS DAO RTR RECY DAO RTR RECY VAC STRP BTMS VAC STRP BTMS



0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

12354 6490 23457 12322

0 0

0 0 35812 18812

55 29 35.8 18.8



I Eng:

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

6490 5864 12322 11134

0 0

0 0 18812 16998

29 27 18.8 17.0

IAprvd:

0 0 0 0 0 0 0 0 0 0 0 0 0

5864 111 34

0

0 16998

27 17.0

I Date: 06/13/2014

24 of 2sl

488 HEADER

VALVE STRPPNG

0 0 0

1050 0 0 0 0 0 0 0 0 0 0 0 0

0 1050

59

1306.4

COMPONENT SUMMARY

VACUUM SECTION






489 490 491 VALVE HEADER VALVE

100-T-402 VALVE MIX STRPPNG STEAM SUPERHTD LPS SUPERHTD LPS

0 0 0 0 0 0 0 0 0

1050 5778 5778 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 1050 5778 5778

59 321 321

1306.4 7188.9 7188.9



I Eng: IAprvd:

I Page

I Date: 06/13/2014

25 of 2sl

STREAM DATA SHEETS












300 100-E-112A/B

100-V-301 ATM TWR FEED

104594 735

224

0.28

34.4

687.0 0.230 0.071 2.650

12

9.35 0.012 0.036 2.341

95.4 594.7

17.3



301 302 100-V-301 100-V-301 100-T-301 100-P-301A/B

LT/MT VAPOR LT/MT OIL

37314 67278 387 348

8676.9 79 9

4253.9 97.4

223 223 243 424

0.26 0.26 3.65 2.38

100.0 0.0 36.2

690.6 0.236 0.072 2.644

0.36

8.77 0.012 0.036 2.334

96.4 785.7 488.7

8.1 9.1

MAT BAL REFLECTS A0.1% CONVERGENCE OF THE PROCESS MODEL.


303 100-P-301A/B

VALVE LT/MT OIL

67278 348

79.9

97.1

223 424

0.92 2.38

0.0 36.2

692.6 0.237 0.072 2.642

0.36

489.7 9.2

IAprvd:

I Page 1 of 251

304 305 VALVE 100-H-301

100-H-301 TRANSFER LINE FURNACE FEED ATM TWRFEED

67278 67278 348 348

79 9

97.2

223 338 424 0.81 0.30 2.38

0.0 65.8 36.2

692.3 654.0 0.237 0.194 0.072 0.057 2.643 2.941

9

14.95 0.012 0.042 2.652 170.7

489.7 941.8 9.2 17.6

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS













306 TRANSFER LINE

100-T-301 ATM TWR FEED

67278 348

334

0.23

70.6

666.7 0.211 0.059 2.925

10

12.49 0.012 0.041 2.630 173.1 941 .8

17.6

308 HEADER

VALVE STRPPNG STEAM

7901 439

9830.3

1958.1

230 374

0.80 22.12 100.0

4.04 0.018 0.036 2.232

18.0 2903.0

6.4




309 VALVE


7901 439

9830.3

4957.3

219 374

0.25 2212 100.0

1.59 0.017 0.035 2.061

18.0 2903.0

6.4

IChkd:

313 HEADER

VALVE STRPPNG STEAM

3500 194

4354.6

867.4

230 374

0.80 22.12 100.0

4.04 0.0 18 0.036 2.232

18.0 2903.0

2.8

IAprvd:

I Page 2 of 251

314 315 VALVE SPLIT

100-T-302 100-T-302 STRPPNG STEAM ATM TOWER PA

3500 132992 194 731

4354.6 159.7

2196.0 199.0

219 237 374 421

0.26 0.22 22.12 2.49 100.0 0.0

38.0

668.3 0.228 0.067 2.695

1.59 0.017 0.035 2.061

18.0 2903.0 526.3

2.8 19.4

!Date: n&:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS










Temperature , °C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt% Vaporized Liquid Deg API



316 317 100-T-302 100-T-301 100-T-301 SPLIT

DSL STRP OVHD ATM TOWER PA

33532 499114 387 2746

8735.7 599.2

4760.8 746.9

231 237 371 421

0.23 0.22 11.95 2.49 100.0 0.0

38.0

668.3 0.228 0.067 2.695

7.04 0.012 0.032 2.294

86.0 996.6 526.3

9.3 73.0




318 SPLIT

1 OO-P-304A/B ATM TOWER PA

366122 2015

439.5

547 9

237 421

0.22 2.49

0.0 38.0

668.3 0.228 0.067 2.695

0.32

526.3 53.5

IChkd:

319 SPLIT

100-T-301 PUMP BACK

76498 421

91.8

113.8

237 421 1.23 2.49

0.0 38.0

672.3 0.231 0.067 2.690

0.32

526.6 11.2

IAprvd:

I Page

320 321 1 OO-P-304A/B SPLIT

SPLIT 100-E-504 ATM TOWER PA ATM TOWER PA

366122 289623 2015 1595

439.5 347.7

544.5 430.8

237 237 421 421 1.25 1.23 2.49 2.49

0.0 0.0 38.0 38.0

672.4 672.3 0.231 0.231 0.067 0.067 2.690 2.690

526.6 526.6 53.6 42.4

!Date: n&:: 1 1 '=I /"n 1 J\

IRev: n

STREAM DATA SHEETS





START OF RU N Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard , m'/[email protected] ° Flow Condition , m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure , Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liqu id Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a )

Vapor Density. kg/m' Vapor Viscosity, cP Vapor K. W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard , Nm'/hr Flow Standard , m'/[email protected] ' Flow Condition, m' /hr Flow Condition, m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt % Vaporized Liquid Deg API



Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

322 100-E-504 100-E-503

ATM TOWER PA

289623 1595

347.7

424.6

225 421 0.99 2.49

0.0 38.0

682.1 0.229 0.069 2.654

495.6 39.9

323 100-E-503 100-E-302

ATM TOWER PA

289623 1595

347.7

411.4

199 421 0.76 2.49

0.0 38.0

704.0 0.268 0.074 2.573

428.6 34.5

•Datum H20 and HC Above 15.6' C Liquid H2 Above 15.6' C Vapor MAT BAL REFLECTS A 0.1 % CONVERGENCE OF THE PROCESS MODEL.


324 100-E-302

VALVE ATM TOWER PA

289623 1595

347.7

408.2

192 421

0.55 2.49

0.0 38.0

709.6 0.280 0.075 2.550

0.1 8

409.8 33.0

IChkd:

324A VALVE

100-T-301 ATM TOWER PA

289623 1595

347.7

408.3

192 421

0.45 2.49

0.0 38.0

709.3 0.280 0.075 2.550

409.8 33.0

IAprvd:

I Page 4 of 2sl

337 338 100-T-301 100-A-301 100-A-301 100-V-302

ATM TWR OVHD ATM TWR RFLX

180255 205840 2262 368 1

50741 .4

25476.7

162 108 309

0.21 0.13 9.12

100.0 23 .5

711.1 0.261 0. 105 2.729

40

7.08 3.27 0.010 0.01 1 0.027 0.026 2.133 1.959

79.6 44.4 808.1 455.0 40.5 26.0

I Date: n ~ 1 1 ~ / "') (1 1 ,.,

!Rev: n

STREAM DATA SHEETS













339 100-V-302

1 OO-P-302NB ATMTWR RFLX

130780 1101

174.9

193.5

108 317

0.13 3.11

0.0 57.4

675.B 0.265 0.096 2.420

0.23

232.9 8.5

340 1 OO-P-302NB

VALVE ATM TWR RFLX

130780 1101

174.9

193.3

108 317

0.62 3.11

0.0 57.4

676.5 0.266 0.096 2.420

0.23

233.6 8.5




340A VALVE

100-T-301 ATMTWR RFLX

130780 1101

1749

193.4

108 317

IChkd:

0.52 3.11

0.0 57.4

676.3 0.266 0.096 2.420

233.6 8.5

341 100-V-302

1 OO-P-307 NB ATM TWR WATER

27016 1498

27.1

28.4

108 374

0.13 22.11

0.0 10.1

951.6 0.272 0.670 4.227

0.13

451.2 3.4

IAprvd:

I Page

341A 1 OO-P-307 NB

VALVE A TM TWR WATER

27016 1498

27.1

28.4

108 374

0.51 22.11

0.0 10.1

951.5 0.274 0.670 4.227

451.7 3.4

5 of 251

341B VALVE

MIX ATM TWR WATER

27016 1498

27.1

28.4

108 374

0.41 2211

0.0 10.1

951 .5 0.273 0.670 4.227

451.7 3.4

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS













342 100-V-302 100-A-302

RLX DRUM VAP

48043 1083

24241.6

14666.0

108 296

0.13 14.24 100.0

3.28 0.011 0.026 1.959 44.4

1057.8 14.1

343 100-A-302

MIX RFLX DRUM VAP

48043 1083

50

0.07

13.9

755.1 0.466 0.131 2.754

52

2.37 0.010 0.035 1.801 36.9

193.1 2.6




343A MIX

100-V-303 RFLX DRUM VAP

48117 1084

50

0.07

13 9

755.2 0.466 0.131 2.754

52

2.37 0.010 0.035 1.801 36.9

193.0 2.6

IChkd:

344 100-V-303

1 OO-P-308NB ATM TWR WATER

11070 613

11.1

11.3

50 373

0.07 22.04

0.0 10.5

981.7 0.351 0.589 4.171

0.01

208.7 0.6

IAprvd:

I Page 6 of 251

345 345A 1 OO-P-308NB VALVE

VALVE MIX A TM TWR WATER ATM TWR WATER

11070 11070 613 613

11.1 11 .1

11.3 11 .3

50 50 373 373

0.51 0.41 22.04 22.04

0.0 0.0 105 10.5

981.7 981 .7 0.353 0.353 0.589 0.589 4.171 4.171

0.01

209.2 209.2 0.6 0.6

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS













346 MIX

SPLIT ATM TWR WATER

38087 2111

38.2

39.6

91 374

0.38 22.09

0.0 10.2

961.2 0.277 0.631 4.206

381 .3 4.0

346A SPLIT

MIX ATM TWR WATER

12502 694

12.5

13.0

91 374

0.38 22.09

0.0 10 .2

961.2 0.277 0.631 4.206

381.3 1.3




347 100-V-303

1 OO-P-303AIB WILD NAPHTHA

30528 295

42.2

43 9

50 279

0.07 3.18

0.0 63.8

695.9 0.328 0.113 2.242

0.17

104.1 09

IChkd:

348 1 OO-P-303AIB

VALVE WILD NAPHTHA

30528 295

42.2

43.8

51 279 1.48 3.18

0.0 63.8

697.2 0.332 0.113 2.242

0.17

106.6 0.9

IAprvd:

I Page 7 of 251

349 350 VALVE 100-V-303

MIX MIX WILD NAPHTHA OVHDVAPOR

30528 6516 295 177

3954.4 42.2

2750.4 43.8

51 50 279 59 1.38 0.07 3.18 5.65

0.0 100.0 63.8

697.0 0.331 0.113 2.242

2.37 0.010 0.035 1.807 36.9

106.6 566.6 09 1.0

!Date: n&:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/[email protected]' Flow Condition, m' /hr Flow Condition , m' /hr

Temperature , °C Pseudo Crit Temp, 'C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMolWt Enthalpy, kJ/kg Enthalpy, MW


Temperature , °C Pseudo Cri t Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosi ty, cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosi ty, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C Vapor MolWt Enthalpy, kJ/kg Enthalpy. MW

350A MIX

100-V-304 SOUR GAS

9694 426

9556.3

7213.3

46 -56

0.06 4.05

100.0

1.34 0.012 0.059 2.206

22.7 553.3

1.5



351 353 100-V-304 100-C-301 100-C-301 100-A-304

SOUR GAS SOUR GAS

9694 9694 426 426

9556.3 9556.3

7545.7 2975.4

46 137 -56 -56

0.05 0.38 4.05 4.05

100.0 100.0

1.28 3.26 0.012 0.014 0.059 O.D75 2.206 2.525

22.7 22.7 553.3 765.1

1.5 2.1



354 100-A-304 100-V-305

SOUR GAS

9694 426

50

0.30

99.2

783.1 0.487 0.143 3.003

57

3.44 0.012 0.060 2.233

22.7 549.8

1.5

IAprvd:

I Page 8 of 251

355 356 100-V-305 100-C-301 100-C-301 MIX

SOUR GAS 2ND STG DSCH

9621 9621 424 424

9510.3 9510.3

2845.2 1053.5

50 141 -58 -58

0.30 1.27 3.98 3.98

100.0 100.0

3.38 9. 13 0.012 0.015 0.060 0.078 2.232 2.563

22.7 22.7 553.0 766.1

1.5 2.0

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS













362 100-V-305

VALVE CONDENSED LIQ

73 2

0.1

0.1

50 353

0.30 18.23

0.0 42.7

787.7 0.492 0.145 3 031

146.9 0

363 VALVE

MIX CONDENSED LIQ

73 2

50

0.09

0.3

789.2 0.496 0.145 3.031

58

2.76 0.010 0.028 1.798 38 .4

146.9 0




370 100-T-302

1 OO-P-305AIB DIESEL

102960 536

121.7

144.9

211 440

0.24 2.74

0.0 35.4

710.5 0.275 0.073 2.596

0.35

453 9 130

IChkd:

371 1 OO-P-305AIB 100-E-301AIB

DIESEL

102960 536

121.7

144.5

212 440

0.96 2.74

0.0 35.4

712.4 0.277 0.073 2.595

454.9 13.0

IAprvd:

I Page 9 of 251

373 374 100-E-301AIB 100-A-303

100-A-303 100-E-304 DIESEL DIESEL

102960 102960 536 536

121.7 121 .7

135.4 124.7

149 50 440 440

0.86 0.73 2.74 2.74

0.0 0.0 35.4 35.4

760 .4 825.7 0.444 1.347 0.081 0.095 2.387 1.992

297.6 80.4 8.5 2.3

!Date: n &:: 1 1 '=I /"n 1 I\


START OF RUN Flow Mass. kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/[email protected] ° Flow Condition , m'/hr Flow Condition , m'/hr

Temperature. °C Pseudo Crit Temp, ' C Pressure , Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosi ty. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a )

Vapor Density. kg/m' Vapor Viscosity, cP Vapor K. W/m/'C Vapor Spec Heat, kJ/kgi°C Vapor Mol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard , m'/hr @15.6 ' Flow Condition, m'/hr Flow Condition, m'/hr



Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat , kJ/kg/' C Surface Tension. dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K. W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy , MW

STREAM DATA SHEETS




375 375A 376 377 100-E-304 VALVE 100-T-301 1 OO-P-306A/B

VALVE OSBL 1 OO-P-306A/B VALVE DIESEL DIESEL ATM TWR BTTMS A TM TWR BTTMS

102960 102960 260891 260891 536 536 554 554

121.7 121.7 270.1 270.1

124.2 124.3 338.1 337.0

45 45 355 355 440 440 653 653 0.63 0.50 0.24 0.80 2.74 2.74 1.67 1.67

0.0 0.0 0.0 0.0 35.4 35.4 14.7 14.7

828.8 828.6 77 1.6 774.2 1.451 1.447 0.478 0.481 0.096 0.096 0.065 0.065 1.968 1.968 2.942 2.942

0.01 0.34 0.24

70.4 70.4 816.8 817.7 2.0 2.0 59.2 59.3

•Datum H20 and HC Above 15.6' C Liqu id H2 Above 15.6' C Vapor MAT BAL REFLECTS A 0. 1 % CONVERGENCE OF THE PROCESS MODEL.


I Page 10 of 2sl

380 38 1 100-T-303 100-T-303 100-T-301 VALVE

ATM STRP VAP ATM STRP BTMS

203 12 65365 174 139

3954.2 67 .8

2666.2 84 .8

401 357 389 660

0.26 0.28 12.06 1.63 100.0 0.0

15.0

771 .0 0.498 0.065 2.955

0.38

7.62 0.015 0.051 2.729 115.1

1344.2 824 .0 7.6 15.0

I Date: n~ 1 1 ~ / "') (1 1 ,.,

!Rev: n

STREAM DATA SHEETS




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/[email protected] ' Flow Condition, m'/hr Flow Condition , m'/hr

Temperature , °C Pseudo Crit Temp, 'C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt% Vaporized Liquid Deg API



END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'ihr Flow Standard, m3/[email protected] ' Flow Condition, m'/hr Flow Condition, m'/hr

Temperature , °C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt% Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosi ty, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/°C VaporMolWt Enthalpy, kJ/kg Enthalpy. MW

382 100-V-123

VALVE LT OIL

59414 515

78.9

82.2

55 287 1.39 3.34

0.0 56.1

723.0 0.334 0.101 2.180

111.0 1.8



383 384 VALVE 100-E-302

100-E-302 1 OO-E-301AIB LT OIL LT OIL

59414 59414 515 515

55 92

0.65 0.54

0.5 2.8

724.9 699.6 0.345 0.276 0.101 0.094 2.179 2.315

19 16

7.54 8.81 0.012 0.012 0.044 0.032 1.902 1.849 26.7 39.8

111 .0 202.5 1.8 3.3



385 100-E-301AIB

MIX LT OIL

59414 515

179

0.44

25.5

653.0 0.206 0.078 2.587

12

11.50 0.011 0.033 2.213

74.8 475.2

7.8

IAprvd:

I Page 11 of 251

386 392 MIX HEADER

100-E-112AIB VALVE ATM FEED STRPPNG STEAM

104594 1600 735 89

1990.7

396.5

202 230 374

0.39 0.80 2212

18.7 100.0

683.1 0.226 0.073 2.601

12

10.35 4.04 0.012 0.018 0.036 0.036 2.279 2.232

79.4 18.0 499.1 2903.0

14.5 1.3

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS













393 VALVE


1600 89

1990.7

915.5

220 374

0.29 22.12 100.0

1.75 0.017 0.035 2 072

18.0 2903.0

1.3

396 SPLIT

VALVE ATM TWR WATER

25585 1420

25.7

26.6

91 374

0.38 22.09

0.0 10.2

961.2 0.277 0.631 4.206

381.3 2.7




396A VALVE

MIX ATM TWR WATER

25585 1420

90

0.28

04

965.2 0.311 0.674 4.205

61

3.04 0.013 0.027 1.536 24 .0

381.3 2.7

IChkd: IAprvd:

I Page 12 of 251

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS

VACUUM SECTION




START OF RU N Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6° Flow Condition , m'/hr Flow Condition , m'/hr

Temperature, °C Pseudo Crit Temp, 'C Pressure , Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosi ty. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a )

Vapor Density. kg/m' Vapor Viscosity, cP Vapor K. W/m/'C Vapor Spec Heat. kJ/kgi°C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard , Nm'/hr Flow Standard , m'/hr @15.6 ' Flow Condition, m'/hr Flow Condition, m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt % Vaporized Liquid Deg API


Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat , kJ/kg/'C Surface Tension. dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

401 OSBL

MIX AIR LEAK

22 0

17.1

509.3

80 -141

33 mm Hg 3.75

100.0

0.04 0.021 0. 105 1.013 28.9 37.1

0

402 MIX

100-ME-401 VAC TWROVHD

17671 947

21231.7

1004034.1

82 370

20 mm Hg 21 .87 100.0

0.02 0.011 0.024 1.872

18.7 2551.2

12.5




403 100-ME-401

OSBL NONCOND'AB LE

375 13

55

0.00

100.0

82 1.9 1.181 0.096 1.992

27

1.08 0.011 0.029 1.71 4 28.9

655.1 0.1

IChkd:

404 100-ME-401

OSBL VAC TWR SLOP

506 2

0.6

0.6

42 473

0.60 2.15

0.0 31.4

851.9 2.215 0.096 1.892

< 0.01

60.4 0

IAprvd:

I Page 13 of 2sl

405 406 100-ME-401 HEADER

OSBL MIX SOUR WATER COIL STEAM

59600 4990 3308 277

6208.5 59.7

1237.2 60.1

42 230 374 374

0.60 0.80 22.12 22. 12

0.0 100.0 10.1

99 1.7 0.628 0.632 4.174

< 0.01

4.03 0.018 0.036 2.232

18.0 176.5 2903.0

2.9 4 .0

I Date: n~ 1 1 ~ / "') (1 1 ,.,

!Rev: n

STREAM DATA SHEETS

VACUUM SECTION





Temperature , °C Pseudo Grit Temp, 'C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a) Wt% Vaporized Liquid Deg API







415 MIX MIX

FURNACE FEED

277896 581

287.1

357.1

352 658

0.57 1.55 0.0

14.4

778.3 0.510 0.066 2.920

802.0 61.9

419 100-H-401

MIX FURNACE EFF

282885 868

374

191 mm Hg

40.6

709.0 0.959 0.064 2.959

17

0.91 0.012 0.037 2.666 190.4 982.7 77.2




421 100-T-401

1 OO-P-408AIB LLVGO

233925 828

261.5

286 9

150 536

22 mm Hg 1.75 0.0

26.4

815.4 0.987 0.091 2.347

< 0.01

306.2 19 9

IChkd:

422 1 OO-P-408AIB

SPLIT LLVGO

233925 828

261.5

286.2

150 536

0.84 1.75 0.0

26.4

817.5 1.080 0.085 2.322

280.5 18.2

IAprvd:

I Page 14 of 251

423 424 SPLIT 100-A-401

100-A-401 SPLIT LLVGO LLVGO

167701 167701 592 592

187.5 187.5

205.2 191 .5

150 50 536 536

0.81 0.71 1.75 1.75 0.0 0.0

26.4 26.4

817.4 875.6 1.080 4.998 0.085 0.097 2.323 1.888

280.5 69.5 13.1 3.2

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS

VACUUM SECTION




Temperature, °C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres. Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density , kg/m' Liquid Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a )


END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/[email protected] ' Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres, Mpa (a) Wt% Vaporized Liquid Deg API




425 SPLIT

100-E-402 LLVGO

11888 42

13.3

13.6

50 536

0.71 1.75 0.0

26.4

875.6 6.466 0.104 1.888

69.5 0.2



425A 100-E-402

VALVE LLVGO

11888 42

13.3

13.5

45 536

0.60 1.75 0.0

26.4

878.4 5.528 0.097 1.862

< 0.01

60.0 0.2

4258 VALVE

OSBL LLVGO

11888 42

13.3

13.5

45 536

0.50 175 0.0

26.4

878.3 5.512 0.097 1.863

60.0 0.2



426 SPLIT

VALVE LLVGO

66222 234

74.0

81.0

150 536

0.81 175 0.0

26.4

817.4 1.080 0.085 2.323

< 0.01

280.5 5.2

IAprvd:

I Page

426A VALVE

MIX LLVGO

66222 234

74.0

81.2

150 536

0.19 1.75 0.0

26.4

816.0 1 068 0.085 2.325

280.5 5.2

I Date: n~ 1 1 ~ / "') (1 1 ,.,

15 of 2sl

4268 MIX

100-T-401 LVGO

293018 906

323.5

356.6

163 566

0.19 1.59

0.0 24.4

821 .8 1.153 0.088 2.392

336.5 27.4

!Rev: n

STREAM DATA SHEETS

VACUUM SECTION











427 SPLIT

VALVE LLVGO

155814 551

174.2

177.9

50 536

0.71 1.75 0.0

26.4

875.6 6.466 0.104 1.888

< 0.01

69.5 3.0



428 VALVE

100-T-401 LLVGO

155814 551

174.2

178.1

50 536

0.21 1.75 0.0

26.4

874.7 4.934 0.097 1.890

69.5 3.0

431 100-T-401

1 OO-P-404AIB LVGO

380691 1128

418.8

483.3

226 576

27 mm Hg 1.53 0.0

23.8

787.7 0.668 0.080 2.642

< 0.01

494.6 52.3



432 1 OO-P-404AIB

SPLIT LVGO

380691 1128

418.8

481.1

227 576 1.23 1.53 0.0

23.8

791.3 0.679 0.081 2.644

496.3 52.5

IAprvd:

I Page

433 SPLIT

VALVE LVGO

78799 234

86.7

99.5

226 576

1.20 1.53 0.0

23.8

791.6 0.763 0.081 2.590

< 0.01

465.0 10.2

!Date: n &:: 1 1 '=I /"n 1 I\

16 of 251

433A VALVE

MIX LVGO

78799 234

86.7

99.9

226 576

0.21 1.53 0.0

23.8

788.5 0.751 0.080 2.592

465.0 10.2

STREAM DATA SHEETS

VACUUM SECTION







END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm' ihr Flow Standard, m3/[email protected]' Flow Condition, m'/hr Flow Condition, m' /hr




435 SPLIT

100-E-405 LVGO

301891 894

332.1

381 .4

226 576 1.2a 1.53 a.a

23.8

791.6 0.763 o.a81 2.590

< a.01

465.a 39.a



436 100-E-405 100-E-403

LVGO

301891 894

332.1

373.3

196 576 t.ao 1.53 a.o

23.8

8a8.8 1.a41 o.a84 2.491

< a.01

389.0 32 .6

437 100-E-403

SPLIT LVGO

301891 894

332.1

369.6

182 576 a.79 1.53 a.o

23.8

816.8 1.229 a.a86 2.441

352.9 29.6

MAT BAL REFLECTS A a.1 % CONVERGENCE OF THE PROCESS MODEL.


438 SPLIT

MIX LVGO

36a82 1a7

39.7

44.2

182 576

a.76 1.53 a.o

23.8

816.7 1.229 o.a86 2.441

352.9 3.5

IAprvd:

I Page


2658a7 788

292 .4

325.5

182 576

a.76 1.53 a.o

23.8

816.7 1.229 a.a86 2.441

352.9 26.1

!Date: n&:: 1 1 '=I /"n 1 J\

17 of 251

439A SPLIT

VALVE LVGO

226795 672

249.5

277.7

182 576

a.76 1.53 o.a

23.8

816.7 1.229 a.a86 2.441

< o.a1

352.9 22.2

STREAM DATA SHEETS

VACUUM SECTION






Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/' C VaporMolWt Entha lpy, kJ/kg Entha lpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'ihr Flow Standard, m3/[email protected]' Flow Condition, m'/hr Flow Condition, m'/hr




4398 VALVE

MIX LVGO

226795 672

249.5

278.2

182 576

0.19 1.53 0.0

23.8

815.2 1.217 0.085 2.442

352.9 22.2




39013 116

42.9

47 .8

182 576

0.76 1.53 0.0

23.8

816.7 1.229 0.086 2.441

352.9 3.8

441 SPLIT

100-T-301 LVGO QUENCH

28283 84

31.1

34.6

180 576

0.76 1.63 0.0

23.9

817.5 1.254 0.086 2.450

< 0.01

349.6 2.7



442 SPLIT

100-T-303 LVGO QUENCH

10729 32

11.8

13.1

180 576

0.76 1.63 0.0

23.9

817.5 1.254 0.086 2.450

<0.01

349.6 1.0

IAprvd:

I Page

443 100-T-401

1 OO-P-405NB HVGO

490493 1212

524.5

624.4

282 627

33 mm Hg 1.37 0.0

19.5

785.6 0.677 0.073 2.810

<0.01

635.3 86.6

!Date: n&:: 1 1 '=I /"n 1 J\

18 of 251

444 100-P-405NB

SPLIT HVGO

490493 1212

524.5

620.5

282 627 1.20 1.37 0.0

19.5

790.5 0.736 0.075 2.742

604.1 82.3

STREAM DATA SHEETS

VACUUM SECTION











445 SPLIT

1 OO-G-403NB HVGO

133639 330

142.9

169.1

282 627 1.20 1.37 0.0

19.5

790.5 0.736 0.075 2.742

< 0.01

604.1 22.4



445A 1 OO-G-403NB

100-T-401 HVGO

133639 330

142.9

169.9

282 627

0.15 1.37 0.0

19.5

786 .4 0.725 0.074 2.744

604.1 22.4

447 SPLIT

100-E-406 HVGO

356852 883

381.6

451.4

282 627 1.20 1.37 0.0

19.5

790.5 0.736 0.075 2.742

< 0.01

604.1 59 9



448 100-E-406

SPLIT HVGO

356852 883

381.6

440.5

247 627 1.00 1.37 0.0

19.5

810.1 1.038 0.078 2.638

511.3 50.7

IAprvd:

I Page

448A SPLIT

100-E-404 HVGO

344534 852

368 .4

425.3

247 627 1.00 1.37 0.0

19.5

810.1 1.038 0.078 2.638

< 0.01

511.3 48 9

!Date: n&:: 1 1 '=I /"n 1 J\

19 of 251

449 100-E-404

SPLIT HVGO

344534 852

368.4

416.2

215 627

0.79 1.37 0.0

19.5

827.8 1.497 0.081 2.533

427.9 41.0

STREAM DATA SHEETS

VACUUM SECTION






Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/"C VaporMolWt Entha lpy, kJ/kg Enthalpy, MW





450 SPLIT

MIX HVGO

272153 673

291.0

328.8

215 627

0.79 1.37 0.0

19.5

827.8 1.497 0.081 2.533

< 0.01

427.9 32.3



451 MIX

100-T-401 HVGO

350955 907

377.7

429.3

218 614

0.17 1.42 0.0

20.5

817.4 1.232 0.081 2.548

436.2 42 .5

452 SPLIT

VALVE HVGO

72378 178

77.4

87.4

215 627

0.79 1.37 0.0

19.5

827.8 1.497 0.081 2.533

< 0.01

427.9 8.6



452A VALVE

MIX HVGO

72378 178

77.4

87.5

215 627

0.69 1.37 0.0

19.5

827.5 1.494 0.081 2.533

427.9 8.6

IAprvd:

I Page

453 MIX

100-A-402 VGO

108463 286

117.1

131.8

204 608

0.63 1.43 0.0

21.0

823.2 1.358 0.083 2.503

402.9 12.1

!Date: n &:: 1 1 '=I /"n 1 J\

20 of 251

454 100-A-402

OSBL VGO

108463 286

117.1

122.5

90 608

0.50 1.43 0.0

21.0

885.6 8.168 0.094 2.045

142.4 4.3

STREAM DATA SHEETS

VACUUM SECTION



START OF RU N Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/[email protected] ° Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, °C Pseudo Crit Temp, ' C Pressure , Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension, dyne/cm Liquid Vpr Press, Mpa (a )

Vapor Density. kg/m' Vapor Viscosity, cP Vapor K. W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard , Nm'/hr Flow Standard , m'/[email protected] ' Flow Condition, m'/hr Flow Condition, m'/hr




Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

455 100-T-401

1 OO-P-406A/B WASH OIL

69675 141

71.6

86.7

329 695

39 mm Hg 1.24 0.0

13.7

803.5 0.913 0.069 2.904

0.01

747.0 14.5



456 1 OO-P-406A/B

SPLIT WASH OIL

69675 141

71.6

86.6

329 695

0.21 1.24 0.0

13.7

804.8 0.883 0.070 2.848

720.6 13.9

457 SPLIT

1 OO-G-402A/B WASH OIL

32204 65

33.1

40.0

329 695

0. 18 1.24 0.0

13.7

804.7 0.882 0.070 2.848

< 0.01

720.6 6.4



458 1 OO-G-402A/B

100-T-401 WASH OIL

32204 65

33.1

40.0

329 695

0. 14 1.24 0.0

13.7

804.5 0.882 0.070 2.848

720.6 6.4

JAprvd:

I Page

459 SPLIT

VALVE WASH OIL

37470 75

38.5

46.6

329 695

0.18 1.24 0.0

13.7

804.7 0.882 0.070 2.848

< 0.01

720.6 7.5

I Date: n~ 1 1 ~ / "') (1 1 ,.,

21 of 2sl

459A VALVE

100-T-401 WASH OIL

37470 75

38.5

46.6

329 695

0.10 1.24 0.0

13.7

804 .3 0.88 1 0.070 2.848

720.6 7.5

JRev: n

STREAM DATA SHEETS

VACUUM SECTION




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm3/hr Flow Standard, m'/h [email protected]' Flow Condition, m' /hr Flow Condition, m' /hr







Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/' C VaporMolWt Enthalpy, kJ/kg Enthalpy. MW

460 100-T-401

1 OO-P-407 NB VAC TWR BTMS

134803 179

131 .5

155.9

335 809

44 mm Hg 0.98

0.0 6.3

864.8 3.265 0.066 2.833

0.01

740.3 27.7

461 1 OO-P-407 NB

100-E-407 VAC TWRBTMS

134803 179

131.5

154 .4

336 809 1.83 0.98

0.0 6.3

873.0 3.374 0.068 2.836

< 0.01

742 .5 27.8




462 100-E-407 100-E-408

VAC TWR BTMS

134803 179

131.5

149.9

278 809 1.46

IChkd:

0.98 0.0 6.3

899.2 6.063 0.072 2.670

< 0.01

572.7 21.4

462A 100-E-408

SPLIT VAC TWR BTMS

134803 179

131.5

147.1

238 809

0.94 0.98

0.0 6.3

916.5 10.326 0.074 2.534

<0.01

467. 1 17.5

IAprvd:

I Page

463 100-E-408

OSBL SDA VAC TWR BTMS

134803 179

131.5

147.3

238 809

0.50 0.98

0.0 6.3

914.9 10.213 0.074 2.536

467.1 17.5

!Date: n&:: 1 1 '=I /"n 1 J\

22 of 251

467 SPLIT

MIX HVGO

12320 30

13.2

15.2

247 627 1.00 1.37 a.a

19.5

810.1 1.038 0.078 2.638

511.3 1.8

STREAM DATA SHEETS

VACUUM SECTION












469 HEADER

VALVE STRPPNG STEAM

4870 270

6059.2

1207.4

230 374

0.80 22.12 100.0

4.03 0.018 0.036 2.232

18.0 2903.0

3.9

470 VALVE


4870 270

6059.2

190234 .4

212 374

44 mm Hg 22.12 100.0

0.03 0.017 0.034 1.939

18.0 2903.0

3.9




480 VALVE

MIX A TM STRP BTMS

65365 139

356

295 mm Hg

1.4

771 .5 0.515 0.065 2.953

15

1.68 0.011 0.035 2.626 221 .2 824.0

15.0

IChkd:

480A MIX

100-T-402 VAC STRP FEED

71144 460

324

139 mm Hg

40.2

826.7 1.288 0.069 2.865

19

0.28 0.016 0.040 2.438

74 .0 992.9

19.6

IAprvd:

I Page 23 of 251

481 482 100-T-402 100-T-402

MIX 100-P-401A/B VAC STRP OVHD VAC STRP BTMS

36381 35812 462 55

10343.3 35.8

229388.4 42.2

316 308 414 754

74 mm Hg 125 mm Hg 18.51 1.22 100.0 0.0

9.8

848.9 2.151 0.068 2.793

0.02

0.16 0.015 0.038 2.499

78 .8 1356.2 679.7

13.7 6.8

!Date: n&:: 1 1 '=I /"n 1 J\

STREAM DATA SHEETS

VACUUM SECTION












483 1 OO-P-401A/B

SPLIT VAC STRP BTMS

35812 55

35.8

42.0

308 754 0.70 1.22 0.0 9.8

851.9 2.285 0.071 2.814

671 .5 6.7

484 SPLIT

VALVE DAO RTR RECY

18812 29

18.8

22.1

308 754

0.67 1.22 0.0 9.8

851.8 2.284 0.071 2.814

0.01

671.5 3.5




485 VALVE

MIX DAO RTR RECY

18812 29

18.8

22.1

308 754 0.38 1.22 0.0 9.8

850.7 2.273 0.070 2.814

671.5 3.5

IChkd:

486 SPLIT

VALVE VAC STRP BTMS

16998 27

17.0

20.0

308 754

0.67 1.22 0.0 9.8

851.8 2.284 0.071 2.814

0.01

671.5 3.2

IAprvd:

I Page 24 of 251

487 488 VALVE HEADER

MIX VALVE VAC STRP BTMS STRPPNG STEAM

16998 1050 27 59

1306.4 17.0

260.2 20.0

308 230 754 374

0.57 0.80 1.22 2212 0.0 100.0 9.8

851.4 2.280 0.070 2.814

4.04 0.018 0.036 2.232

18.0 671.5 2903.0

3.2 0.8

!Date: n &:: 1 1 '=I /"n 1 I\

STREAM DATA SHEETS

VACUUM SECTION








END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'ihr Flow Standard, m'[email protected]' Flow Condition, m'/hr Flow Condition, m'/hr




489 VALVE


1050 59

1306.4

7281.6

212 374

243 mm Hg 22.12 100.0

0.14 0.017 0.034 1.956

18.0 2903.0

0.8

490 HEADER

VALVE SUPERHTD LPS

5778 321

7188.9

1432.0

230 374

0.80 22.12 100.0

4.04 0.018 0.036 2.232

18.0 2903.0

4.7




491 VALVE

MIX SUPERHTD LPS

5778 321

7188.9

32792.3

212 374

295 mm Hg 2212 100.0

0.18 0.017 0.034 1.958

18.0 2903.0

4.7

IChkd: IAprvd:

I Page 25 of 251

!Date: n&:: 1 1 '=I /"n 1 J\

IRev: n

4.0 - 1

4.0 - LIGHT ENDS RECOVERY SECTION

4.1 Process description

4.1.1 Introduction

The following is a description of the light ends recovery section scheme as depicted on Process Flow Diagram BF-133116. The light ends recovery section is designed to separate the sour gas, non-permeate gas from the Membrane Unit, and wild naphtha into sour gas (to be treated by the Flash Gas Amine Absorber), LPG, and Naphtha. LPG is treated in a common LPG treatment located in the Hydrocracker battery limits . .

4.1.2 Light Ends Recovery Section

The liquid from the Atmospheric Tower Overhead Product Dmm and Lean Oil Absorber (1OO-T-501) bottoms mixes with the vapor from the Sour Gas Compressor, LT Oil Flash Drum, non-penneate tl-om the Membrane Unit, and the Deethanizer (1 OO-T-502) overhead vapor. This mixed feed is cooled by the Deethanizer Overhead Air Cooler (100-A-501) and the Deethanizer Overhead Trim Cooler (1 OO-E-502), after which the partially condensed liquid flows into the Deethanizer Reflux Dmm (100-V-502). The sour water is sent on interface level control to the sour water degasser in the reaction section. The vapor from the 1 OO-V-502 is fed on pressure control to the bottom of the Lean Oil Absorber.

The liquid from the 1 OO-V-502 is pumped on flow control reset by the reflux drum level by the Deethanizer Reflux Pumps (100-P-503A/B) to the top of the Deethanizer, which has 28 valve trays. The column has a thermosyphon reboiler, the Deethanizer Reboiler (100-E-503), which exchanges heat with the Atmospheric Tower pumparound. The Deethanizer bottoms is sent on flow control reset by level to the Naphtha Stabilizer (1 OO-T-503) .

The Naphtha Stabilizer removes C4's and lighter material from the naphtha. This column also has a thermosyphon reboiler, the Naphtha Stabilizer Reboiler (100-E-504), which exchanges heat with the Atmospheric Tower pumparound. The stabilizer overhead vapor is totally condensed in the Naphtha Stabilizer Overhead Air Cooler (1 OO-A-502) before being subcooled to 40 °C in the Naphtha Stabilizer Overhead Cooler (1 OO-E-506) and flowing into the Naphtha Stabilizer Reflux Drum (100-V-503) through a pressure control valve.

The Naphtha Stabilizer overhead is totally condensed in an air cooler, half of whose fan motors are variable speed. The condensed liquid then flows into the Naphtha Stabilizer reflux drum after passing through the "A" pressure control valve. The control valve should be very close to the reflux drum inlet nozzle. In addition, the line from the air cooler to the reflux drum must be free-draining towards the reflux drum with no pockets in the line. Finally, the air cooler must be installed high enough above the reflux drum to provide sufficient hydraulic head to overcome any flow resistance due to the piping and the control valve.




4.0 - 2

Pressure in the column is controlled by varying the position of the "A" control valve in the overhead line. The control valve restricts the flow of liquid from the air cooler and causes it to back up into the air cooler tubes . The air cooler, therefore, is operated in a partially flooded mode. The amount of condensation is controlled by the amount of "un-flooded" area. The "flooded" area will sub-cool the liquid. The column pressure is then controlled by changing the area available for condensation. At a steady overhead flow rate, restricting the flow of liquid will reduce the area for condensation, thereby raising the column pressure. Opening the control valve will increase the area for condensation and reduce the column pressure.

A pressure equalizing line with a control valve between the colunm overhead and the reflux drnm is used to vent any non-condensable vapors that build up at the air cooler inlet and cause the column pressure to increase. Normally the "B" control valve in the equalizing line operates wide open, and the "A" control valve throttles the liquid flow from the condenser as described above. If the column overhead pressure rises such that the "A" control valve is wide open, then the "B" control valve closes to force the overhead vapor through the condenser. If noncondensables accumulate in the reflux drum and the overhead pressure rises above the set point of the pressure controller in the reflux drum vent line, then the pressure control valve on the vent line opens to allow the vapors to vent to the flare .

LPG is pumped by the Naphtha Stabilizer Reflux Pumps (100-P-504A/B) from the Naphtha Stabilizer Reflux Drum on flow control reset by drnm level to the LPG treating system within the Hydrocracking Unit. Some of the condensed LPG is routed back to the stabilizer as reflux on flow control. Any sour \vater is sent OSBL to SWS.

The bottoms product from the Naphtha Stabilizer is pumped by the Naphtha Stabilizer Bottoms Pumps (1 OO-P-505A/B) on flow control reset by column level and cooled in succession by the Naphtha Product Air Cooler (100-A-503) and the Naphtha Product Trim Cooler (100-E-505). A portion of this stream is returned to the Lean Oil Absorber Reflux Drum (l OO-V-501) to be used as sponging medium in the Lean Oil Absorber to recover LPG, while the balance is sent OSBL as Naphtha product.

The vapor from 100-V-501 is mixed with offgases from the Rich Amine Flash Drum and Sour Water Degasser and sent to the Flash Gas Centrifugal Separator (1 OO-V-126) to ensure no liquid entrainment. The mixed offgas is then scrubbed using amine in the Flash Gas Amine Absorber (100-T-103) to remove H2S. Once the gas has been scrubbed in the H2S absorber, it enters the Flash Gas KO drum (100-V-127) where any entrained amine is knocked out. The sweet fuel gas is sent OSBL on pressure control. At high pressure setpoint, the pressure controller will vent to the flare line. The rich amine stream leaving 100-T- l 03/ 1 OO-V-127 is combined with rich amine leaving the Rich Amine Flash Drum and sent to the OSBL ARU.




J>

td ..,., I

...... w w

4.3 Stream Data

This section contains the light ends recovery section stream data and component balances for normal operating conditions. Included are component balance sheets showing detailed component breakdown and stream data sheets showing flow rates and physical properties for each stream.







COMPONENT SUMMARY

LIGHT ENDS RECOVERY



501 502 503 504 1 OO-V-123 VALVE MIX MIX

VALVE MIX MIX 100-A-501 SOUR GAS SOUR GAS WILD NAPHTHA DEC2 OVHD

83 83 650 655 331 331 1532 2121

0 0 1 2 6 6 254 276

149 149 4703 4975 185 185 3612 4506 216 216 4332 6090

76 76 2119 2738 68 68 2119 2766

0 0 0 0 0 0 0 0

87 87 31079 47115 1 1 1356 2098 0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 1202 1202 51757 73342

74 74 1272 1559

1674.0 1674.0



I Eng: IAprvd:

I Page

505 100-A-501 100-E-502

DEC2 OVHD

655 2121

2 276

4975 4506 6090 2738 2766

0 0

47115 2098

0 0 0

0 73342

1559

I Date: 06/13/2014

1 of 101

506 100-E-502 100-V-502

DEC2 OVHD

655 2121

2 276

4975 4506 6090 2738 2766

0 0

47115 2098

0 0 0

0 73342

1559




COMPONENT SUMMARY

LIGHT ENDS RECOVERY



507 507A 508 509 1 OO-V-502 1 OO-P-503A/B VALVE 100-V-502

1 0 O-P-503A/B VALVE 100-T-502 VALVE DEC2 REFLUX DEC2 REFLUX DEC2 REFLUX SOUR WATER

4 4 4 0 457 457 457 0

0 0 0 0 17 17 17 167

211 211 211 0 694 694 694 0

2212 2212 2212 0 1589 1589 1589 0 1806 1806 1806 0

0 0 0 0 0 0 0 0

46055 46055 46055 0 2096 2096 2096 0

0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 55141 55141 55141 167

612 612 612 9 79.7 79 .7 79.7 0.2



I Eng: IAprvd:

I Page

509A VALVE

MIX SOUR WATER

0 0 0

167 0 0 0 0 0 0 0 0 0 0 0 0 0 0

167 9

0 .2

I Date: 06/13/2014

2 of 101

510 100-T-502

MIX DEC2 OVHD

4 456

0 17

211 693

1116 159 130

0 0

177 0 0 0 0

0 2963

85

1901 .9




COMPONENT SUMMARY

LIGHT ENDS RECOVERY



511 512 513 514 100-V-502 VALVE 100-T-502 100-E-503

VALVE 100-T-501 100-E-503 100-T-502 SOUR GAS SOUR GAS DEC2 BOILUP DEC2 BOILUP

651 651 0 0 1664 1664 4 4

1 1 0 0 91 91 0 0

4763 4763 0 0 3812 3812 1 1 3878 3878 6090 6090 1148 1148 5860 5860 961 961 6454 6454

0 0 0 0 0 0 0 0

1060 1060 89172 89172 2 2 3395 3395 0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 18031 18031 110976 110976

937 937 1239 1239 161.4

21000.1 21000.1



I Eng: IAprvd:

I Page

515 100-T-502

VALVE DEC2BTTMS

0 0 0 0 0 0

1096 1431 1676

0 0

45877 2095

0 0 0

0 52175

528 73.5

I Date: 06/13/2014

3 of 101

516 VALVE

100-T-503 DEC2 BTTMS

0 0 0 0 0 0

1096 1431 1676

0 0

45877 2095

0 0 0

0 52175

528

COMPONENT SUMMARY

LIGHT ENDS RECOVERY



Stream No 517 518 519 519A From 100-T-503 100-T-503 100-A-502 100-E-506 To 1 0 O-P-505A/B 100-A-502 100-E-506 100-V-503 Content NPTH STAB BTM NPTH STAB OHO NPTH STAB OHO NPTH STAB OHO



0 0 0 3 0 0 0 0 0 0 0 0 0 4987

10 6463 38 7452

0 0 0 0

45829 222 2095 0

0 0 0 0 0 0

0 0 47972 19127

449 355 65.9

7970.4



I Eng:

0 0 3 3 0 0 0 0 0 0 0 0

4987 4987 6463 6463 7452 7452

0 0 0 0

222 222 0 0 0 0 0 0 0 0

0 0 19127 19127

355 355 34.5 34.5

IAprvd:

I Page

520 100-V-503

1 OO-P-504A/B LPG

0 3 0 0 0 0

4987 6463 7452

0 0

222 0 0 0 0

0 19127

355 34.5

I Date: 06/13/2014

4 of 101

521 1 OO-P-504A/B

SPLIT LPG

0 3 0 0 0 0

4987 6463 7452

0 0

222 0 0 0 0

0 19127

355 34.5




COMPONENT SUMMARY LIGHT ENDS RECOVERY



522 523 524 525 SPLIT VALVE SPLIT VALVE

VALVE 100-T-503 VALVE OSBL LPG REFLUX LPG REFLUX LPG PROD LPG PROD

0 0 0 0 2 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

3890 3890 1096 1096 5042 5042 1421 1421 5814 5814 1638 1638

0 0 0 0 0 0 0 0

173 173 49 49 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 14921 14921 4204 4204

277 277 77 77 26.9 26 .9 7.6 7.6



I Eng: IAprvd:

I Page

526 100-T-503 100-E-504

STAB BOILUP

0 0 0 0 0 0 0

44 157

0 0

93741 3418

0 0 0

0 97360

941 134.7

I Date: 06/13/2014

5 of 101

527 100-E-504 100-T-503

STAB BOILUP

0 0 0 0 0 0 0

44 157

0 0

93741 3418

0 0 0

0 97360

941

COMPONENT SUMMARY

LIGHT ENDS RECOVERY





531 100-T-501

1 0 O-P-502A/B ABSORBER BTMS

1 133

o 5

61 200 642 460 518

0 0

15859 742

0 0 0

0 18621

201 26.7


532 533 1 OO-P-502A/B VALVE

VALVE MIX ABSORBERABSORBER BTMS

1 1 133 133

o o 5 5

61 61 200 200 642 642 460 460 518 518

0 0 0 0

15859 15859 742 742

0 0 0 0 0 0

o 0 18621 18621

201 201 26 .7 26.7



I Eng:

534 100-T-501

MIX ABSORBER

650 1640

1 90

4756 3779 3706 933 661

0 0

1500 4 0 0 o

o 17720

927

20773.9

IAprvd:

I Page

535 MIX

100-E-501 ABSORBER

650 1640

1 90

4756 3779 3706

937 675

0 0

17740 746

0 0 0

0 34720

1087

I Date: 06/13/2014

6 of 101

536 100-E-501 100-V-501

ABSORBER

650 1640

1 90

4756 3779 3706

937 675

0 0

17740 746

0 0 0

0 34720

1087

COMPONENT SUMMARY I Page LIGHT ENDS RECOVERY



Stream No 537 537A 539 540 541 From 100-V-501 VALVE 100-V-501 100-P-501A/B VALVE To VALVE MIX 100-P-501 A/B VALVE 100-T-501 Content SOUR GAS SOUR GAS ABSORBER RFLX ABSORBER RFLX ABSORBER RFLX



650 650 1531 1531

1 1 86 86

4703 4703 3612 3612 3236 3236

692 692 456 456

0 0 0 0

1442 1442 3 3 0 0 0 0 0 0

0 0 16412 16412

895 895

20063.2 20063.2



I Eng:

1 1 109 109

0 0 4 4

53 53 167 167 470 470 244 244 219 219

0 0 0 0

16298 16298 743 743

0 0 0 0 0 0

0 0 18308 18308

189 189 25.9 25.9

IAprvd:

1 109

0 4

53 167 470 244 219

0 0

16298 743

0 0 0

0 18308

189 25.9

I Date: 06/13/2014

7 of 101

542 100-V-122

MIX SOUR GAS

24 35

0 7

11 6 5 0 0 0 0 3 0 0 0 0 0 0

91 14

319.3




COMPONENT SUMMARY

LIGHT ENDS RECOVERY



543 543A 544 544A MIX 100-V-126 SPLIT VALVE

1 OO-V-126 100-T-103 VALVE 100-T-103 SOUR GAS SOUR GAS LEAN AMINE LEAN AMINE

681 681 0 0 1643 1643 44 44

1 1 0 0 95 95 22899 22899

4716 4716 0 0 3620 3620 0 0 3242 3242 0 0

692 692 0 0 457 457 0 0

0 0 0 0 0 0 0 0

1445 1445 0 0 3 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 15267 15267

16595 16595 38210 38210 915 915 1400 1400

37.7 37 .7 20524 .2 20524.2



I Eng: IAprvd:

I Page

545 100-T-103

VALVE RICH AMINE

0 1686

1 22772

1 1 0 0 0 0 0 0 0 0 0 0 0

15267 39728

1441 39.6

I Date: 06/13/2014

B of 101

545A VALVE

MIX RICH AMINE

0 1686

1 22772

1 1 0 0 0 0 0 0 0 0 0 0 0

15267 39728

1441 39.6


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 cs -16S c 16S - 360 c 360 - sso c SSO C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std . Flow, m'/hr @1 Total Vap. Std. Flow, Nm'/hr


COMPONENT SUMMARY

LIGHT ENDS RECOVERY



546 S47 S47A SS2 100-T-103 100-V-127 VALVE 100-P-SOSA/B 100-V-127 VALVE OSBL 100-A-S03

SWEET GAS SWEET GAS SWEET GAS STAB BTMS

681 681 681 0 1 1 1 0 0 0 0 0

223 223 223 0 471S 471S 471S 0 3618 3618 3618 0 3241 3241 3241 0

692 692 692 10 4S7 4S7 4S7 38

0 0 0 0 0 0 0 0

144S 144S 144S 4S829 3 3 3 209S 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

1S076 1S076 1S076 47972 874 874 874 449

6S.9 19S97.1 19S97.1 19S97.1



I Eng: IAprvd:

I Page

SS3 100-A-S03

SPLIT STAB BTMS

0 0 0 0 0 0 0

10 38

0 0

4S829 209S

0 0 0

0 47972

449 6S.9

I Date: 06/13/2014

9 of 101

SS4 SPLIT

VALVE LEAN OIL

0 0 0 0 0 0 0 4

14 0 0

16240 743

0 0 0

0 17001

1S9 23.4


START OF RUN COMPONENT, kg/hr H2 H2S NH3 H20 C1 C2 C3 iC4 nC4 N2 02 C5 -165 C 165 - 360 c 360 - 550 c 550 C+ VR FEED DAO RX FEED MDEA Total Mass Flow, kq/hr Total Molar Flow, kq-moles/hr Total Liq. Std. Flow, m'/hr @1 Total Yap. Std. Flow, Nm'/hr


COMPONENT SUMMARY

LIGHT ENDS RECOVERY



555 556 557 558 SPLIT 100-E-505 VALVE VALVE

1 OO-E-505 VALVE OSBL MIX NAPHTHA NAPHTHA NAPHTHA LEAN OIL

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6 6 6 4

24 24 24 14 0 0 0 0 0 0 0 0

29588 29588 29588 16240 1353 1353 1353 743

0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 0 30971 30971 30971 17001

290 290 290 159 42.5 42 .5 42.5 23.4



I Eng: IAprvd:

I Page

I Date: 06/13/2014

10 of 101

STREAM DATA SHEETS

LIGHT ENDS RECOVERY



START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm' /hr Flow Standard, m'/hr @15.6° Flow Condition, m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres. Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/m/' C Liquid Spec Heat, kJ/kg/'C Surface Tension , dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/°C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Enthalpy , MW

END OF RUN Flow Mass, kg/hr Flow Molar. kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6' Flow Condition, m'/hr Flow Condition, m'/hr

Temperature , ' C Pseudo Crit Temp, 'C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension , dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density , kg/m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Entha lpy. kJ/kg Entha lpy , MW

501 100-V-123

VALVE SOUR GAS

1202 74

1674.0

134.3

55 -110 1.39 3.40

100.0

8.95 0.013 0.080 2.567

16.1 580.3

0.2

•Datum H20 and HC Above 15.6' C Liquid H2 Abcve 15.6' C Vapor


502 503 VALVE MIX

MIX MIX SOUR GAS WILD NAPHTHA

1202 51757 74 1272

1674.0

148.1

54 72 -110 1.25 1.25 3.40

100.0 38.9

656.9 0.234 0.106 2.347

15

8.12 10.31 0.013 0.013 0.080 0.064 2.562 2.391

16.1 21 .3 580.3 310.8

0.2 4.5


Confidential II Eng : IChkd:

504 MIX

100-A-501 DEC2 OVHD

73342 1559

65

1.22

30.2

658.6 0.238 0. 107 2.325

15

10.55 0.012 0.059 2.323

21 .9 259.5

5.3

IAprvd:

I Page 1 of 101

505 506 100-A-50 1 100-E-502 100-E-502 100-V-502

DEC2 OVHD DEC2 OVHD

73342 73342 1559 1559

50 38

1.17 1.12

26.9 24.6

667.2 673.9 0.257 0.275 0.111 0.113 2.278 2.240

17 18

9.87 9.30 0.012 0.012 0.058 0.057 2.330 2.340 20.3 19.2

211.9 174.6 4.3 3.6

I Date: (I C, 1 -1 ~ l"' il I ,1

!Rev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY



START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6' Flow Condition , m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Grit Temp, °C Pressure, Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'ihr @15.6' Flow Condition , m'/hr Flow Condition , m'/hr

Temperature , ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres, Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg /m' Liquid Viscosity. cP Liquid K, W/m/' C Liquid Spec Heat, kJ/kg/'C Surface Tension , dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity. cP Vapor K, W/m/' C Vapor Spec Heat. kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

507 100-V-502

1 OO-P-503NB DEC2 REFLUX

55141 612

79.7

81.9

38 235 1.12 3.47

0.0 72.7

673.2 0.271 0. 113 2.234

1.22

82.6 1.3

•Datum H20 and HCAbove 15.6' C Liquid H2 Above 15.6°C Vapor


507A 508 100-P-503N B VALVE

VALVE 100-T-502 DEC2 REFLUX DEC2 REFLUX

55141 55141 612 612

79.7 79.7

81.9 81.9

38 38 235 235 1.53 1.43 3.47 3.47

0.0 0.0 72.7 72.7

673.6 673.4 0.272 0.272 0.113 0.113 2.234 2.235

83.4 83.4 1.3 1.3

MAT BAL REFLECTS A 0.1% CONVERGENCE OF TH E PROCESS MODEL.


509 100-V-502

VALVE SOUR WATER

167 9

0.2

0.2

38 374 1.12

22.12 0.0

10.1

993.5 0.677 0.627 4. 173

0.01

160.3 0

IAprvd:

I Page 2 of 101

509A 510 VALVE tOO-T-502

MIX MIX SOUR WATER DEC20VHD

167 2963 9 85

1901 .9 0.2

161 .5 0.2

38 59 374 53

0.82 1.22 22.12 5.31

0.0 100.0 10.1

979.4 0.676 0.627 3.587

18.35 0.011 0.029 1.935 34.9

161.9 478.9 0 0.4

jDate: (\~ /1 -;i /')f\1 11

!Rev: n



Temperature, ' C Pseudo Crit Temp, °C Pressure, Mpa (g) Pseudo Grit Pres. Mpa (a) Wt % Vaporized Liquid Deg A PI

Liquid Density, kg /m' Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/'C Surface Tension , dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg /m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'ihr @15 .6' Flow Condition , m'/hr Flow Condition , m'/hr

Temperature , ' C Pseudo Crit Temp, °C Pressure, Mpa (g) Pseudo Cnt Pres. Mpa (a) Wt % Vaporized Liquid Deg AP I

Liquid Density, kg /m' Liquid Viscosity. cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/' C Surface Tension , dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg /m' Vapor Viscosity. cP Vapor K, W/m/'C Vapor Spec Heat. kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

STREAM DATA SHEETS

LIGHT ENDS RECOVERY


511 100-V-502

VALVE SOUR GAS

18031 937

21000.1

1938.8

38 -79

1.12 3.74

100.0

9.30 0.012 0.057 2.340

19.2 456.1

2.3


512 513 VALVE 100-T-502

100-T-50t 100-E-503 SOUR GAS DEC2 BOILUP

18031 110976 937 1239

21000.1 161.4

2147.4 199.9

38 141 -79 238

1.00 1.29 3.74 3.33

100.0 0.0 73.9

555.3 0.120 0.088 2.678

840 0.012 0.057 2.333

19.2 456.1 334.8

2.3 10.3

514 100-E-503 100-T-502

DEC2 BOILUP

110976 1239

180

1.25

30.0

539.7 0.107 0.078 2.805

6

31.82 0.012 0.038 2.461

73.4 509.8

15.7




I Page

515 100-T-502

VALVE DEC2 BTTMS

52175 528

73.5

96.7

180 265 1.25 3.17

0.0 67.3

539.6 0.107 0.078 2.805

1.35

433.1 6.3

jDate: (\~ /1 -;i /')f\1 11

3 of 101

516 VALVE

100-T-503 DEC2 BTTMS

52175 528

175

1.03

5.3

552.2 0.116 0.080 2.768

7

27.02 0.011 O.D35 2.408

75.2 433.1

6.3

!Rev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY





Temperature, ' C Pseudo Crit Temp , °C Pressure, Mpa (g) Pseudo Grit Pres. Mpa (a) Wt % Vaporized Liquid Deg API

Liquid Density, kg /m' Liquid Viscosity, cP Liquid K, W/m/' C Liquid Spec Heat, kJ/kg/'C Surface Tension , dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg /m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy , kJ/kg Enthalpy , MW


Temperature, ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres, Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg /m' Vapor Viscosity. cP Vapor K, W/m/' C Vapor Spec Heat. kJ/kg/'C Vapor Mol Wt Enthalpy , kJ/kg Enthalpy , MW

517 100-T-503

1 OO-P-505A/B NPTH STAB BTM

47972 449

65.9

90.1

208 288

0.97 3.04

0.0 62.5

532.3 0.102 0.068 2.900

1.07

505.4 6.7

518 100-T-503 100-A-502

NPTH STAB OHO

19127 355

7970.4

795.3

66 130

0.93 3.89

100.0

24.05 0.010 0.021 2.186

53.8 459.8

2.4

•oatum H20 and HG Above 15.6' C Liquid H2 Above 15.6°C Vapor



519 100-A-502 100-E-506

NPTH STAB OHO

19127 355

34.5

37.7

50 130

0.88 3.89

0.0 123.0

507.2 0.104 0.090 2.667

125.1 0.7

IChkd:

519A 100-E-506 100-V-503

NPTH STAB OHO

19127 355

34.5

36.6

40 130

0.83 3.89

0.0 123.0

522.6 0.114 0.094 2.593

98.8 0.5

IAprvd:

I Page 4 of 101

520 521 100-V-503 100-P-504A/B

1 OQ-P-504A/B SPLIT LPG LPG

19127 19127 355 355

34.5 34 .5

36.6 36.4

40 42 130 130

0.81 2.82 3.89 3.89

0.0 0.0 123.0 123.0

522.5 525.4 0.114 0.115 0.094 0.093 2.593 2.572

0.70

98.8 103.6 0.5 0.6

jDate: (\ ~ /1 ~ /')f\1 11

!Rev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY




Temperature, ' C Pseudo Crit Temp , °C Pressure, Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg /m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy , kJ/kg Enthalpy , MW


Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres. Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg /m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/'C Vapor Mol Wt Enthalpy , kJ/kg Enthalpy , MW

522 SPLIT

VALVE LPG REFLUX

14921 277

26.9

28.4

42 130

2.79 3.89

0.0 123.0

525.3 0.115 0.093 2.572

103.6 0.4

•Datum H20 and HCAbove 15.6' C Liquid H2 Above 15.6°C Vapor


523 524 VALVE SPLIT

100-T-503 VALVE LPG REFLUX LPG PROD

14921 4204 277 77

26.9 7.6

28.7 8.0

42 42 130 130 1.14 2.79 3.89 3.89

0.0 0.0 123.0 123.0

520.7 525.3 0.113 0.115 0.093 0.093 2.600 2.572

0.73

103.6 103.6 0.4 0.1



525 VALVE

OSBL LPG PROD

4204 77

7.6

8.0

42 130

2.69 3.89

0.0 123.0

525.1 0.115 0.093 2.574

103.6 0.1

IAprvd:

I Page 5 of 101

526 527 100-T-503 100-E-504 100-E-504 100-T-503

STAB BOILUP STAB BOILUP

97360 97360 941 941

134.7

182.2

199 208 281 1.00 0.97 3.10

0.0 30.0 63.9

534.2 532.3 0.103 0.102 0.068 0.068 2.878 2.900

5

32.42 0.011 0.034 2.527

96.8 484.1 576.2

13.1 15.6

jDate: (\ ~ /1 ~ /')f\1 11

!Rev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY




START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6° Flow Condition , m'/hr Flow Condition, m'/hr

Temperature, ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres. Mpa (a) Wt% Vaporized Liquid Deg API

Liquid Density, kg/m' Liquid Viscosity, cP Liquid K, W/m/'C Liquid Spec Heat, kJ/kg/'C Surface Tension , dyne/cm Liquid Vpr Press, Mpa (a)

Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/°C Vapor Spec Heat, kJ/kg/' C VaporMol Wt Enthalpy, kJ/kg Entha lpy , MW

END OF RUN Flow Mass, kg/hr Flow Molar. kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6° Flow Condition, m'/hr Flow Condition, m'/hr

Temperature , ' C Pseudo Grit Temp, 'C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a ) Wt % Vaporized Liquid Deg API


Vapor Density , kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat , kJ/kg/'C VaporMol Wt Entha lpy. kJ/kg Entha lpy , MW

531 100-T-501

100-P-502NB ABSORBER BTMS

18621 201

26.7

27.4

38 243

0.96 3.41

0.0 71.0

679.6 0.286 0.114 2.225

1.06

813 0.4

532 100-P-502NB

VALVE ABSORBER BTMS

18621 201

26.7

27.4

38 243 1.39 3.41

0.0 71.0

680.0 0.286 0.114 2.224

1.07

82.1 0.4

· oatum H20 and HC Above 15.6' C Liquid H2 Above 15.6' C Vapor


Confidential II Eng :

533 VALVE

MIX ABSORBER BTMS

18621 201

26.7

27.4

38 243 1.29 3.41

0.0 71.0

679.8 0.286 0. 114 2.225

82.1 0.4

IChkd:

534 100-T-501

MIX ABSORBER OVHD

17720 927

20773.9

2321.1

42 -81

0.92 3.73

100.0

7.63 0.012 0.059 2.349

19.1 467.2

2.3

JAprvd :

I Page 6 of 101

535 536 MIX 100-E-501

100-E-501 100-V-501 ABSORBER OVHD ABSORBER OVHD.

34720 34720 1087 1087

48 40

0.92 0.87

49.0 47.3

681.6 686.4 0.286 0.300 0. 112 0.114 2.251 2.222

18 18

7.35 6.98 0.012 0.012 0.062 0.060 2.389 2.384

18.8 18.3 289.5 264.4

2.8 2.6

I Date : (IC, 1 -1 ~ l"'il I ,1

JRev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY




Temperature, ' C Pseudo Crit Temp , °C Pressure, Mpa (g) Pseudo Grit Pres. Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg /m' Vapor Viscosity. cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy , kJ/kg Enthalpy , MW


Temperature, ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres, Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg /m' Vapor Viscosity, cP Vapor K, W/m/' C Vapor Spec Heat, kJ/kg/'C Vapor Mol Wt Enthalpy , kJ/kg Enthalpy , MW

537 100-V-501

VALVE SOUR GAS

16412 895

20063.2

2352.1

40 -86

0.87 3.69

100.0

6.98 0.012 0.060 2.384

18.3 464.4

2.1



537A 539 VALVE 100-V-501

MIX 100-P-501NB SOUR GAS ABSORBER RFLX

16412 18308 895 189

20063.2 25.9

2633.8 26.7

40 40 -86 253

0.77 0.87 3.69 3.34

100.0 0.0 68.6

686.4 0.300 0.114 2.222

0.97

6.23 0.012 0.060 2.378

18.3 464.4 85.1

2.t 0.4



540 100-P-501NB

VALVE ABSORBER RFLX

18308 189

25.9

26.7

40 253 1.21 3.34

0.0 68.6

686.7 0.301 0.114 2.222

0.97

85.7 0.4

IAprvd:

I Page 7 of 101

541 542 VALVE 100-V-122

100-T-501 MIX ABSORBER RFLX SOUR GAS

18308 91 189 14

319.3 25.9

45.4 26.7

40 68 253 -183 1.10 0.79 3.34 2.69

0.0 100.0 68.6

686.5 0.301 0.114 2.222

2.01 0.012 0.081 4.909

6.4 85.7 1094.6

0.4 0

jDate: (\ ~ /1 -;i /')f\1 11

!Rev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY



START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6° Flow Condition , m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres. Mpa (a) Wt% Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/°C Vapor Spec Heat, kJ/kg /' C VaporMol Wt Entha lpy , kJ/kg Enthalpy , MW

END OF RUN Flow Mass, kg/hr Flow Molar. kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6' Flow Condition , m'/hr Flow Condition , m'/hr

Temperature , ' C Pseudo Crit Temp, ' C Pressure, Mpa (g) Pseudo Crit Pres , Mpa (a) Wt% Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat , kJ/kg/'C VaporMol Wt Entha lpy. kJ/kg Entha lpy , MW

543 MIX

100-V-126 SOUR GAS

16595 915

20524.2

2698.6

40 -88

0.77 3.68

100.0

6.15 0.016 0.061 2.403

18.1 466.3

2.1



543A 544 100-V-126 SPLIT 100-T-103 VALVE

SOUR GAS LEAN AMINE

16595 38210 915 1400

20524.2 37.7

2742.2 37.4

40 50 -88 376

0.75 2.45 3.68 20.44

100.0 0.0 7.7

1020.7 2.271 0.337 3.732

0.02

6.05 0.016 0.061 2.402

18.1 466.3 171 .6

2.1 1.8



544A VALVE

100-T-103 LEAN AMINE

38210 1400

37.7

37.4

50 376

0.79 20.44

0.0 7.7

1020.7 2.271 0.337 3.732

171.6 1.8

IAprvd:

I Page 8 of 101

545 545A 100-T-103 VALVE

VALVE MIX RICH AMINE RICH AMINE

39728 39728 1441 1441

39.6 39.6

38.6 38.6

59 59 367 367

0.75 0.65 20.05 20.05

0.0 0.0 9.3 9.3

1028.1 1028.1 1.637 1.637 0.340 0.340 3.524 3.524

149.2 149.2 1.6 1.6

I Date : (IC, 1 -1 ~ l"'il I ,1

!Rev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY



START OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6° Flow Condition , m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres. Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity, cP Vapor K, W/m/°C Vapor Spec Heat, kJ/kg /' C VaporMol Wt Entha lpy , kJ/kg Enthalpy , MW

END OF RUN Flow Mass, kg/hr Flow Molar. kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6° Flow Condition , m'/hr Flow Condition , m'/hr

Temperature, ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres , Mpa (a ) Wt % Vaporized Liquid Deg API


Vapor Density , kg/m' Vapor Viscosity, cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Entha lpy. kJ/kg Entha lpy , MW

546 100-T-1 03 100-V-127

SWEET GAS

15076 874

19597.1

2807.8

51 -95

073 3.54

100.0

5.37 0.012 0.041 2.578

17.2 503.8

2.1

· oatum H20 and HC Above 15.6' C Liquid H2 Above 15.6' C Vapor


547 547A 100-V-127 VALVE

VALVE OSBL SWEET GAS SWEET GAS

15076 15076 874 874

19597.1 19597.1

2831.4 3871.5

51 50 -95 -95

0.72 0.50 3.54 3.54

100.0 100.0

5.32 3.89 0.012 0.012 0.04 1 0.04 1 2.578 2.564

17.2 17.2 503.8 503.8

2.1 2.1



552 100-P-505NB

100-A-503 STAB BTMS

47972 449

65 9

89.7

208 288 1.47 3.04

0.0 62.5

534.6 0.102 0.068 2.889

506.6 6.8

IAprvd:

I Page

553 100-A-503

SPLIT STAB BTMS

47972 449

659

68.2

50 288 1.34 3.04

0.0 62.5

703.3 0.355 0.114 2.233

104.2 1.4

I Date: (IC, 1 -1 ~ l"'il I ,1

9 of 101

554 SPLIT

VALVE LEAN OIL

17001 159

23.4

24.2

50 288 1.31 3.04 0.0

62.5

703.2 0.355 0. 114 2.233

0.03

104.2 0.5

!Rev: n

STREAM DATA SHEETS

LIGHT ENDS RECOVERY




Temperature, ' C Pseudo Crit Temp, °C Pressure, Mpa (g) Pseudo Grit Pres. Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity. cP Vapor K, W/m/'C Vapor Spec Heat, kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

END OF RUN Flow Mass, kg/hr Flow Molar, kg-moles/hr Flow Standard, Nm'/hr Flow Standard, m'/hr @15.6' Flow Condition , m'/hr Flow Condition , m'/hr

Temperature , ' C Pseudo Grit Temp, ' C Pressure, Mpa (g) Pseudo Grit Pres, Mpa (a) Wt % Vaporized Liquid Deg API


Vapor Density, kg/m' Vapor Viscosity. cP Vapor K, W/m/' C Vapor Spec Heat. kJ/kg/'C VaporMol Wt Enthalpy, kJ/kg Enthalpy, MW

555 SPLIT

100-E-505 NAPHTHA

30971 290

42.5

44.0

50 288 1.31 3.04

0.0 62.5

703.2 0.355 0.114 2.233

104.2 0.9



556 100-E-505

VALVE NAPHTHA

30971 290

42.5

43.6

40 288 1.24 3.04

0.0 62.5

711.2 0.390 0.116 2.193

0.02

82.0 0.7

557 VALVE

OSBL NAPHTHA

30971 290

42.5

43.6

40 288

0.50 3.04

0.0 62.5

710.0 0.386 0.116 2.196

82.0 0.7

MAT BAL REFLECTS A 0.1% CONVERGENCE OF TH E PROCESS MODEL.


558 VALVE

MIX LEAN OIL

17001 159

23.4

24.2

50 288 1.10 3.04

0.0 62.5

702.9 0.354 0.114 2.234

104.2 0.5

IAprvd:

I Page 10 of 101

jDate: (\ ~ /1 -;i /')f\1 11

!Rev: n

5.0 - 1

5.0 - CATALYST HANDLING SECTION

5 .1 Process Description

5 .1.1 Basis of Design

The following is a description of the Catalyst Handling Section as depicted on the Process Control Diagrams BF-13 313 7 through BF-13 313 9. The purpose of the catalyst handling system is to transfer fresh catalyst into and withdraw spent catalyst ±1-om the reactors on a daily basis, while the unit is on-stream. In this manner reactor catalyst activity can be maintained to achieve desired processing needs without requiring shutdown of the unit to replace the catalyst invent01y.

In addition, facilities are provided to:

• Receive and store fresh catalyst. • Load initial charge of catalyst. • Withdra\v and reload equilibrium catalyst during a turnaround. • Remove oil from spent catalyst and load spent catalyst into rail road cars or trncks for removal

from the site.

Catalyst (contents of one transfer vessel) is added to a reactor 3 times every 2 days. Spent catalyst is withdrawn, cooled and transferred to catalyst de-oiling bins, from where it is unloaded for disposal, after de-oiling.

The system has been designed and the sequence of operations is developed so as to minimize the impact on other units , which are in communication with the catalyst system. There are two oil circulating loops within the system: a hot transport oil loop which is used to heat the catalyst, transfer catalyst to and from the reactors, and initially wash the spent catalyst; and a cold oil loop used to cool the spent catalyst and transfer it into the catalyst de-oiling bins. Hot and cold oils are blended during intermediate stages of heating and cooling to prevent sudden, large changes in temperature.

The sources of cooling and transport oil are:

• Cooling Oil

• Transport Oil

Atmospheric Diesel Diesel from storage

HVGO from Vacuum Tower VGO from storage (backup) Diesel from storage

The cooling oil circuit will basically be a closed loop with a small quantity of make-up and purge from the system. The purge will be routed to the fractionation system.




5.0-2

The transport oil accumulated in the Slop Drnm during heating and cooling operations is also routed to the fractionation system.

The design basis and criteria used in specifying the system for operating the unit are outlined below:

Catalyst ICR-622 ICR-630 Catalyst Addition Rate

Normal (kg/MT) 0.57 0.47 Design (kg/MT) 0.74 0.61

Catalyst Consumption, Normal (kg/day) 4200 3460 Design (kg/day) 5460 4500

Cycle (hours) I Batch 10 to 13

Catalyst Batch I Train Normal (kg) 5600 4615 Design (kg) 7280 6000

Catalyst Density Fresh (kg/m3

) 497 545

100-R-101 100-R-102 & 103 Catalyst Inventory in Reactor

Reactor Size, Dia x T-T (mm) 4013 x 35966 ( 3 reactors) Catalyst Volume (m 3)/ reactor 290 290 Catalyst Weight (kg)/ reactor 144130 158050

Frequency of Fresh Catalyst Addition 3 batches (total) per 48 hours

Transport Oil Circulating Rate:

Operation Heating m'/h Catalyst Addition m'/h Catalyst Withdrawal m'/h Washing Cooling

m'/h 1113/h




Rate 40 27 27 20 21

5.0 - 3

Cooling Oil Circulating Rate:

Operation Rate Heating m3/h 20 Cooling m3/h 42 Catalyst Transfer m3/h 34

The following sequential operations are automatic, to be controlled by the DCS:

• Daily Catalyst Addition and Withdrawal • Transfer Fresh Catalyst from Fresh Catalyst Transport Pot to Inventory Holding Bins

or Transfer Vessels

The following operations are manual:

• Equilibrium Catalyst Withdrawal and re-addition from/to reactors (during turnarounds) • Fresh Catalyst Handling • Unload Shipping Containers (from trucks or other transport means selected) • Drain Oil from De-Oiling Bins • Unload De-Oiled Spent Catalyst into shipping bins, railroad cars or trucks for removal from

the site

5. l.2 Fresh Catalvst Handling

It is assumed that the fresh catalyst is shipped fi.-0111 the catalyst manufacturer in containers each containing approximately 3 tons of catalyst. The catalyst flows by gravity from the fresh catalyst container into the Fresh Catalyst Transport Pot (FCTP 100-V-604).

The FCTP operations i.e. de-oxygenation, oil filling, catalyst transfer from FCTP to Inventory Holding Bins and emptying FCTP are controlled by the DCS according to the FCTP operating sequence which is independent of the daily addition/withdrawal sequence.

Catalyst is slurried from either the Fresh Catalyst Transport Pot or the Catalyst Inventory Bins into the Catalyst Transfer Vessels l OO-V-60 l A/B according to the daily catalyst addition/withdrawal sequence. The Fresh Catalyst Transport Pot capacity is sufficient for 7-days of catalyst inventory at the design addition rate.

5 .1.3 Daily Catalyst Addition/Withdrawal

The daily catalyst addition/withdrawal operating sequence is controlled by the DCS, as described below.

Catalyst transfer to and fi.-0111 each reactor occurs, on average, every l 0-13 hours under normal conditions during a full cascading mode through two reactors. In addition, catalyst may be added to or withdrawn from any reactor individually.




5.0 - 4

Operating the Unit with Full Cascading Through Two Reactors

The daily catalyst addition/withdrawal operating sequence comprises the following major steps:

0. Check initial status of system. 1. Slurry fresh catalyst from FCTP or Inventory Holding Bin into the transfer vessel l OO-V-

60 lA 2. Heat catalyst and Transfer Vessel 612-V-601A, Phase I. 3. Heat catalyst and Transfer Vessel 612-V-601A, Phase II. 4. Pressure the Trans fer Vessels and HP transport header. 5. Withdraw equilibrium catalyst from Reactor 100-R-103 [R3] into Transfer Vessel 100-V-

601B . 6. Add fresh catalyst from Transfer Vessel 100-V-601A into Reactor 100-R-103 [R3]. 7. Withdraw equilibrium catalyst from Reactor 100-R-102 [R2] into Transfer Vessel 100-V-

601A. 8. Add equilibrium catalyst from Transfer Vessel 100-V-601B into Reactor 100-R-102 [R2]. 9. Wash spent catalyst in transfer vessel 100-V-601A with HVGO. 10. Depressurize the high pressure system. 11. Cool spent catalyst and Transfer Vessel 100-V-601A - Phase I. 12. Cool spent catalyst and Transfer Vessel 1OO-V-601 A - Phase II. 13 . Transfer spent catalyst from Transfer Vessel 100-V-601A to Spent catalyst De-Oiling Bin

100-V-609 A or B.

The above steps assume that Trans fer Vessel 1 OO-V-60 l A was chosen by the operator to receive fresh catalyst at the beginning of the procedure. If 100-V-601B were chosen for the fresh catalyst instead, the same sequence would occur, except 1 OO-V-60 l B would be substituted for 100-V-601A.

Subsets of the add/withdraw steps are available to provide operational flexibility.

The above operation requires about 10-13 hours to complete . Under normal conditions the above steps will be repeated every 16 hours.

5 .1.4 Spent Catalyst Handling

The transfer of catalyst from Transfer Vessel 1OO-V-601 A or B to Spent Catalyst De-Oiling Bins 100-V-609A or B is executed automatically via the DCS system. However, the draining and discharging operations are manual.

As catalyst shmy is transferred to the Catalyst De-Oiling Bin, 1 OO-V-609 A,B, the oil drain line will normally be open, allowing the oil to immediately drain into the Cooling Oil Surge Drum, 100-V-603. To ensure good draining of the oil, the temperature of the catalyst/oil mixture should be about 40-50°C. Steam coils are provided on the bottom cone of the Catalyst De-Oiling Bins to maintain the desired temperature. After the desired amount of sluny has been




5.0 - 5

transferred, the contents of the Catalyst De-Oiling Bin are allowed to discharge by gravity either into shipping bins, rail road cars or trncks for removal from the site.

5 .1.5 Equilibrium catalyst withdrawal

The 3" HP catalyst transport header is used to transport the slurry directly from the Reactors to the Catalyst Inventory Holding Bins. Prior to unloading catalyst the reactors will have been depressurized to about 4.0 MPa(g), while the pressure in the Catalyst Inventory Holding Bin is being controlled at approximately 3.0 MPa(g) . The unloading commences once the reactor temperatures have been reduced to 230 °C and continues as the reactors are cooled to 65 °C . The spool in the HP catalyst transport header is aligned to connect the transport header directly to the Catalyst Inventory Holding Bins via XV-3678A,B. Diesel supplied via the Cooling Oil Circulating Pumps is used to transport the catalyst to the Catalyst Inventory Holding Bins. The Reactor pressure and transport oil rate are controlled to give the desired slurry concentration of approximately 30 vol.%. The catalyst settles out in the Catalyst Invent01y Holding Bins while the oil overflows to the Cooling Oil Surge Drum via the Oil Drain Surge Drum. Excess oil accumulated in the Cooling Oil Surge Drum is pumped to OSBL tankage.

The withdrawal of equilibrium catalyst is a manual operation. However, certain passive interlocks will have to be bypassed to enable equilibrium catalyst withdrawal operations to be performed. The time required to transfer the contents of each Reactor to the Catalyst Inventory Holding Bin is approximately 24 hours .

5 .1.6 Equilibrium catalyst addition (following turnaround)

When re-commissioning the unit after a turnaround, the equilibrium catalyst held in the Catalyst Inventory Holding Bins is transferred to the Reactors via the 3" HP catalyst transport header. This operation is performed manually. Similar to equilibrium catalyst withdrawal, certain passive interlocks will have to be bypassed to enable equilibrium catalyst addition operations to be performed.

During this operation the Reactors will be at a pressure of about 3. 7 MPa (g) and temperature of between 80 and 260 °C. To re-inventory the reactors , one spool piece is required .The spool piece will be connected from the re-inventory header to the transport header. Make-up hydrogen will be used to pressurize the Catalyst Invento1y Holding Bins to the required pressure of 4.7 MPa (g) oil and catalyst will flow from catalyst Inventory Holding Bins, bypass the transfer vessels and flow via the transfer header to the reactors. Cooling oil is pumped from the cooling oil drum to the re-inventoty header to provide "carrier oil" for the catalyst. After the reactors have been reinventoried, the make-up hydrogen is disconnected from the Catalyst Inventory Holding Bins and nitrogen is re-connected. The Catalyst Invento1y Holding Bins are purged of the hydrogen with nitrogen up to 0.6 MPa(g) . The time required to transfer the contents of each Invent01y Holding Bin to each of the reactors is approximately 24 hours.




5.2 Process Control Diagrams

5.0-6



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6.0 - 1

6.0 - PROCESS CONTROL STRATEGY

6.1 Design Philosophy

It is intended that the LCMAX Residue Hydrocracking Plant be controlled by a Distributed Control System (DCS). Safety functions shall be perfonned in a separate safety interlock system (SIS). The primaiy operator interface will be through a computer based display monitor in the main control room which forms pait of the DCS.

Both the DCS and SIS must be on an uninterruptible power supply (UPS).

All systems supplied must have full and functional redundancy that is fully transparent to the overall control system.

For further details regarding the DCS, SIS, and UPS system, please refer to the appropriate appendices.

It is assumed that the temperature surveillance system is implemented in the DCS. Temperature surveillance may be performed in a redundant DCS supervisory computing module or in the controller substation.

CONFIDENTIAL

PROPERTY OF CLG TO BE REPRODUCED, AND USED, ONLY IN

ACCORDANCE WITH WRITTEN PERMISSION OF


6.0 - 2

6.2. Continuous Control Philosophy: Reactor Temperature Surveillance System

The Temperature Surveillance System is designed to safeguard the reactors against a maldistribution of temperatures and to calculate the average temperature for reactor control.

This is achieved by comparing all reactor skin and internal duplex thermocouples against the evaluation criteria to assess whether the catalyst bed is properly expanded and/or whether reactor operability limits have been reached.

6.2. 1 Temperature Instrumentation

Associated with each reactor are a total of them1ocouples: 85 skin duplex them1ocouples plus 22 internal duplex thennocouples. Twenty one of the internal duplex thermocouples are equally distributed in three internal wells with 1 located in the bottom head of the reactor. Of the 85 skin duplex thennocouples, 48 are distributed in four rings immediately above the distribution grid with 12 in each ring. Of the remaining 37 duplex thermocouples, 33 are equally distributed in eleven rings, located from 6,098 mm to 27,024 nun above the BTL, while 4 are located on the bottom head of the reactor.

Refer to P&IDs drawings BD-133337 through BD-133342 for Reactor 100-R-101 the1111ocouple locations, drawings BD-133344 tlu·ough BD-133349 for Reactor 100-R-1 02 them1ocouple locations,, and drawings BD-133355 tlu·ough BD-133360 for Reactor 100-R-103 them1ocouple locations.

The thermocouples are brought back into the DCS through two independent DCS I/O subsystems (or in any fully redundant maimer).

Both temperature signals from each duplex the1111ocouple are brought back into the rack room tlu-ough separate thermocouple junction boxes and independent cables . One of these temperature signals is given an A series designation and the other a B series number. The series A thermocouples are c01mected to one DCS I/O subsystem and the B series are connected to another DCS I/O subsystem.

The A and B series thermocouples are totally independent of each other and a partial or total failure in one of the series has no effect on the other.

Selected B series them1ocouples are to be connected to the SIS I/O system utilizing repeater relays or other secure method. The SIS shall be furnished with an operator station located in the control room to allow the operator to monitor selected B them1ocouples in the event of a shortterm outage of the DCS operator stations. The SIS operator station may also serve as an engineering station and does not need to be located in the DCS consoles . The SIS operator station shall be furnished power from an independent power source from tl1e DCS operator stations to avoid the risk of conm1on mode failure.

All thermocouple and thennocouple wire shall be the special calibration type that provides

CONFIDENTIAL




6.0 - 3

minimum eITor tolerance .

6.2.2 Application Philosophy

All 214 thermocouple indications (per reactor) will be available to the operator. However, only one thermocouple of each duplex pair will be scanned at any given time by the Temperature Surveillance System. The thermocouples used by the temperature application will be selectable by the operator from the main control room.

The temperature application will, however, perform two fi.mctions for all 214 them1ocouples:

Provide a rate of change alarm. Provide a differential temperature alarm between any duplex pair.

All other application functions are downstream of the pair selector.

The following application description will deal only with the selected thermocouples of the 107 pairs.

The application will use six of the internal thermocouples, which are representative of the average temperature to calculate a reactor average temperature. All the skin thennocouples in Rings L, M, N and 0 and internal thermocouples (including thermocouples used for average calculation) are then compared to the reactor average and a deviation of any of these points exceeding the maximum limit will cause a mal-distribution cutback.

CONFIDENTIAL




6.0 - 4

For the thermocouples in the four rings inm1ediately above the distribution grid (Ring L, M, N and 0), an average temperature is calculated for each ring. Each them1ocouple within a ring is then compared to its ring average temperature imd a deviation of any of these points exceeding the maximum limit will cause a mal-distribution cutback. This comparison for the Ring L, M , N and 0 thermocouples is in addition to the comparison to the reactor average. During normal operating conditions, there will be a slight temperature gradient along the vertical axis of the reactor and around the circumference. The maximum allowable temperature deviation to the reactor and ring averages would therefore all be of different values. To get around this problem, bias factors have been added to all internal thermocouples and Ring L, M , N and 0 thern10couples.

The internal thermocouples have one bias factor added to them to compensate for the vertical temperature gradient m1d the ring thermocouples have two bias factors added. One compensates for the vertical temperature gradient and the other compensates for the temperature gradient around the circumference of the reactor.

With these cotTection factors added, all them1ocouples will now indicate the same temperature and the cutback deviation value will now be a constant.

All 107 selected the1111ocouple raw temperah1re values are checked for a high and high-high temperature. A high temperature will activate automatic cutbacks. A high-high temperahire will activate the automatic cutbacks.

Some bypassing of thennocouples from the reactor surveillance system is allowed but with restrictions as follows:

A limited number of the1111ocouple pairs may be bypassed from any cutback or depressurizing criterion if it is detennined that the thermocouple is faulty. This, however, is allowed only at a supervisory level (Level 2) .

Reactor average comparison criteria and ring average comparison criteria may also be bypassed, but this function is restricted to an engineering level (Level 3).

The hardware and software system for each reactor must be set up such that the surveillance system for each reactor is executed once eve1y 15 seconds.

6.2 .3 Temperature Surveillance Logic

Temperature signals from each duplex thermocouple sen es are continuously scaimed by the DCS.

All individual thermocouples are to be corrected by online configuration, such that the thermocouple indication is equal to a local calibration them1ocouple reading on any point. This is to cotTect for transmission problems and thermocouple calibration correction factors. The corrected the1111ocouple input is used by the temperature surveillance strategy application.

CONFIDENTIA L




6.0 - 5

A selector switch is to be provided to select the A or B series thermocouple, for each individual pair, for the surveillance strategy. The ability to switch to the primary (A series) or backup (B series) is to be under operator control. In the event of a failure (A series), this switch shall automatically switch all selector switches to the B series simultaneously.

An inhibit switch is to be provided to inhibit the above automatic switchover. These inhibit and reset switches are under engineer key lock (Level 3).

A differential temperahire alarm is required for each duplex pair, and each thermocouple will be provided with a high temperature alann and a rate of change alarm.

6.2.3 .l Internal Delta Temperature Calculations

However, if both the A and B series thermocouple of a conunon duplex pair are under high alarm conditions, bypassing of that duplex pair is not allowed.

The reactor average temperahire is used for reactor temperature control and to assess proper temperature distribution throughout the reactor.

All internal thermocouples have a bias factor added to them. This bias factor is added to compensate for the slight temperature gradient along the vertical axis of the reactor. Under normal operating conditions the corrected (normalized bias factor added) thermocouple indications of all internals should be identical and equal to the reactor average.

The corrected temperature of each of these thennocouples is then compared to the reactor average (which was calculated from uncon-ected temperatures). Any offset from zero would therefore represent a maldistribution. Depending on the severity of the deviation, certain actions are taken. A prealann is to be provided before any actions are taken.

The calculated reactor average will be used as the reactor tempera hire for the purposes of reactor temperature control. During failure of this calculated reactor average (e.g., failure of the hardware perfonning the calculation), the highest of three (preselected from the six internal thermocouples used to calculate the reactor average temperature) will be used as the reactor temperature for the purposes of control.

For full details on the temperature control application refer to Section 6.3.0.

I emperature deviation indication and deviation alarms are to be provided to show the deviation between the reactor average temperahire and the oil/hydrogen feed into the reactor.

Under failure of the reactor average temperature calculation the backup reactor temperature will be used in place of the reactor average tempera hire for the deviation indication and alarms.

If the cutback signal is generated by only one of the 21 internal thennocouples, a 15-mi.nute

CONFIDENTIAL




6.0 - 6

timer is activated. If the high temperature deviation condition exists for the full 15 minutes, a reactor auto-cutback is started as per criteria l in Table 6.2.3-1.

If the cutback signal is generated by two or more of the 21 internal thennocouples, a 5-minute timer is activated. If the high temperature deviation on two or more thennocouples exists for the full 5 minutes, a reactor auto-cutback is started.

If the temperature condition which activated the 5 or 15-minute timer is cleared before the timer times out, the timers will be reset to zero.

A cutback bypass is to be provided such that the cutback signal from the 5 or 15-minute timer for all twenty-one internal signals can be bypassed. This bypass switch is under key lock and has engineering level access only.

6.2.3.2 Internal Thennocouple Malfunction Activation Logic

If any of the coffected values of the 21 internal thennocouples deviate by plus or minus 7°C from the calculated reactor average, a cutback signal is to be generated as per criterion l in Table 6.2.3-1.

Under thermocouple failure conditions, a maximum of one of the six internal them1ocouples used to calculate the reactor average may be bypassed, and then only if both thermocouples of that duplex pair are not in high alarm. The bypass switches are to be under supervisory key lock.

Under thennocouple failure conditions, a maximum of three of the fifteen internal temperature corrected thennocouples (those not used in the reactor average calculation) may be bypassed and then only if both thermocouples of each of these duplex pairs are not in high alann. The bypass switches are to be under supervisory key lock.

6.2.3.3 Skin Delta Temperature Calculation

All skin thennocouples in Rings L, M, N and 0 have two bias factors added to them. The first bias factor is added to compensate for temperature deviations within a ting around the reactor circumference. Once this bias factor has been added, all thermocouples within a ring should be equal to their ring average.

The second bias factor is added to compensate for temperahire deviations along the vertical axis of the reactor. This bias factor compensates for the difference between the ring average and the reactor average. After this bias factor has been added, all thermocouples in each of the four rings should be equal to the calculated reactor average.

A ting average calculation is required for Rings L. M, N and 0. The ring average is calculated

CONFIDENTIAL




6.0 - 7

by discarding the highest imd lowest of the twelve rmg thennocouples and averagmg the remaining ten.

A provision is to be made to allow the supervisory level bypass of two duplex pairs of the twelve thennocouples such that only eight would be used in the average calculation. A maximum of two duplex pairs per ring will be allowed to be bypassed. However, if both the A and B series thermocouples of a common duplex pair are under high alann conditions, bypassing of that duplex pair is not allowed. The ring average is used to determine if there is a temperature maldistribution at the ring elevation of the reactor.

6.2.3.4 Skin Thermocouple Malfunction Activation Logic

The bias corrected temperature of each them1ocouple in Rings, L, M, N and 0 is compared to its ring average. An offset above crite1ia limits would represent a maldistribution. Depending on the severity of the deviation, certain actions are taken.

The bias cotTected temperature of each thermocouple in Rings L, M, N and 0 is compared to the reactor average. An offset above crite1ia limits would represent a maldistiibution. Depending on the severity of the deviation, certain actions are taken.

The deviation allowed for thermocouples in Ring 0 will be slightly higher than for the thermocouples in Rings L, Mand N.

1. If any of the twelve skin thennocouples in each of the four Rings L, M, N and 0 deviate by plus or minus 7°C from its calculated ring average, a cutback signal is to be generated. Under thermocouple failure conditions a maximum of two of these signals, per ring, may be bypassed and then only if both thermocouples of that duplex pair are not in high alarm. The bypass switches are to be under supervisory key lock.

2. If any of the twelve skin thermocouples in each of the three Rings L, M, and N deviate by plus or minus 11 °C or plus or minus l 3°C in Ring 0 from the reactor average, a cutback signal is to be generated. Bypass conditions for these signals is identical to those listed in Item 1.

3. If any one of the skin thennocouples in Rings L, M, N and 0 exceeds the maximum deviation allowed from its ring average (see Item l) a 15 minute timer is activated. If the high temperature deviation condition exists for the full 15 minutes, the reactor autocutback is started.

If two or more thennocouples in any of the four rings exceed the maximum deviation allowed, a 5-minute timer is activated. If the high temperature deviation exists for the full five minutes, a reactor auto cutback is started.

If the temperature conditions which activated the 5 or 15-minute timer are cleared before the timer times out, the timers will be reset to zero.

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6.0 - 8

A cutback bypass is to be provided such that the cutback signal from the 5 and 15-minute timer for all of the thermocouple signals can be bypassed.

4. If any one of the skin them10couples in Rings L, M, and N exceed the maximum deviation allowed from the reactor average, a 15-minute and/or 5-minute timer is activated, depending on the number of thermocouples which deviate. Conditions for timers, actions and bypass access is identical to those listed in Item 3 above.

5. If any one of the skin thennocouples in Ring 0 exceeds the maximum deviation allowed from the reactor average, a 15-minute and/or 5-minute ti.mer is activated depending on the number of thermocouples, which deviate. Conditions for timers, actions and bypass access is identical to those listed in Item 3 above.

6. The thermocouples in Rings A through K all have pair bypass switches . A maximum of one of the six pairs is allowed to be bypassed at any one time. However, if both the A and B series thermocouple of a conunon duplex pair are in high alann, bypassing of that pair is not allowed. The switches are under key lock and have supervisory access level only.

7. The thermocouples in Rings L, M, N and 0 all have pair bypass switches . A maximum of one of the twelve pairs is allowed to be bypassed at any one time. However, if both the A and B series thermocouple of a common duplex pair are in high ala1111, bypassing of that pair is not allowed. The switches are under key lock and have supervisory access level only.

6.2.3.5 High and High-High Temperature Malfunction Activation

All thennocouples (the selected A or B se1ies) are scmmed for high temperature.

The thennocouples included in this scan are the internal thermocouples plus all skin thermocouples in Rings A through 0. The temperature value checked, in all cases, is the calibrated the1111ocouple reading from the DCS 1/0 subsystem before the reactor bias factors have been added.

If any one of the above temperatures exceeds 445°C a 1-minute timer is activated. If this temperature condition exists for a period of 1 minute or longer, a reactor auto cutback is generated.

If the condition clears before the 1-minute time setting the 1-minute timer is reset to zero.

If the temperah1re exceeds the value of 460°C, an automatic depressurization is immediately activated. There are no bypass switches for the 1-minute timer which activates a reactor auto cutback or for the high-high temperahJre switch which activates the reactor depressurization. There are however, individual pair bypass, as previously described, on all of the thermocouples

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6.0 - 9

scanned. If any of these switches is in the bypass mode, the thennocouple pair associated with that switch will no longer be scanned for high temperature.

NOTE:

When a thermocouple pair is bypassed, that pair will no longer be used for any reactor or ring, average calculation or for any of the criteria cutbacks.

If both thermocouples of a bypassed pair go into alarm, that pair will not be permitted to be switched back into the surveillance application until at least one of the thermocouple alarms clears .

The condition and impact of crite1ia 1 to Salb inclusive are sunm1arized in Table 6.2.3-1 following.

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Table 6.2.3-1 Reference Table for Cutback Criteria

Cutback Number of

Criteria Description

Pre-alarm Trip

Sensors to Time Delay Number Point (cC)

Point (cC) Trigger (Minutes) Cutback

Delta T between any 1 lS

1 internal TIC

±S ±7 (after nornrnlization)

2 ormore s and the reactor temperature

Delta T between any skin T/C 1 lS

2 In Ring 0

±9 ±13 (after N ormaliza ti on)

2 or more s and the reactor temperature

Delta T between any skin T/C 1 lS

3 In Rings L. M and N

±7 ±II (after N ormaliza ti on)

2 ormore s and the reactor temperature

Delta T between any skin T/C In Rings L. M. N and 0 1 lS

4 (after N ornrnliza ti on) ±S ±7 and their respective ring 2 ormore s average temperature

Sa High temperature on any of

441 44S 1 ormore 1 the internal or skin T/C's

High High temperature on Sb any of the internal or skin 460 1 ormore No time delay

T/C's

NOTE: Criteria I. 2, 3, 4, and Sa activate malfunction HS-xxxx A. B. or C (see Section 6.6 for further details). depending on which reactor had the mal-distribution.

Criteria Sb activates malfunction HS-xxxx A. B. or C (see Section 6.6 for further details) depend on which reactor had the mal-distribution.

CONFIDENTIAL PROPERTY Of CLG

TO BE REPRODUCED AND USED ONLY IN ACCORDANCE WITH WRITTEN PERMISSION OF


6.0 - 11

6.2.4 Operator/Engineering Interface

As a minimum the following values shall be continually monitored and available for display to operator or engineering personnel.

6.2.4. l Indicators

1. Calibrated thermocouple indications for all points.

2. The average temperature for Rings L, M, N and 0 with and without bias, the average temperature of the 15 internal the1111ocouples not used in the reactor average, and the calculated reactor average temperature.

3. Temperature deviations between calculated reactor average and all normalized (the1111ocouple temperature plus all bias factors added) internal and Rings L, M, N and 0 them10couples.

4. Temperature deviations between the normalized ring average temperatures (Rings L, M, N and 0) and the normalized skin thermocouple signals in those tings.

5. All normalized temperatures for the internal thermocouples and the thermocouples m Rings L, M, N and 0.

6. Running time for all cutback timers .

6.2.4.2

1. High temperature prealarms.

2. Rate of change alaims on all thennocouples.

3. Differential alarm between the A and B se1ies thennocouples.

4. Pre-cutback alarm for high/ low differential temperature between normalized internal thermocouples and thermocouples in Rings L, M, N and 0 and the calculated reactor average temperature.

5. Cutback alarms for the thermocouples (listed in 4) above.

6. Pre-cutback alarm for high differential temperature between no1111alized the1111ocouples in Rings L, M, N and 0 and their respective calculated ring average.

7. Cutback alan11S for the the1111ocouples listed in 6) above.

8. High temperature cutback and depressurization alarm.

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9. Alarms to indicate that a selector or bypass switch is not in normal mode.

6.2.4.3 Switches

1. A switch to select either one or the other thermocouple of a duplex pair for the reactor temperature surveillance application.

The normal switch position will be such that an A series thermocouple is employed in the surveillance application. The switch can be switched to the backup B series if a primary A series thermocouple fails.

These switches have an operator access level.

2. A pair bypass switch is to be provided for all duplex pairs.

This switch will take out a pair from the reactor surveillance system.

Refer to Section 6.2.3 for a detailed list on program imposed inhibits for this set of selectors.

The switch is to be under key lock operation and will have supervisory access level only.

3. A bypass switch is to be provided for the following cutback criteria: 1, 2, 3, and 4.

Though a cutback condition exists, the switch would prevent the cutback from being initiated.

The switch is to be under key lock operation and will have engineering access level only.

4. The following system switches are to be provided:

An auto transfer inhibit switch to prevent the application computer from switching all the selector switches to the backup mode on failure of the A series DCS I/O subsystem.

This s\vitch is to be under key lock and is to have an engineering access level only.

A switch to reset all the selector switches back to their primary mode after an auto switch over has occlmed or to manually set all the selector switches to the B series thennocouples. This switch is to have an operator access level.

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6.3 Continuous Control Philosophy: Reactor Temperature Control

The objective of the reactor temperature control system is to maintain the average temperature of each of the reactors to within specified tolerance limits. Each reactor temperature is controlled independently by a cascade control loop. For the first LCMAX reactor, the average temperature is cascaded to the inlet mixed phase temperature controller, which in turn is cascaded to reactor feed furnace firing control system. In the second LCMAX reactor, the average temperature is cascaded to the inlet mixed phase temperature controller, which in tum is cascaded to the quench gas I quench oil flow controllers. For the DAO LCMAX reactor, the average temperature is cascaded to the inlet mixed phase temperature controller, which in tum is cascaded to DAO reactor feed furnace firing control system.

63 . l First LCMAX Reactor Temperature Control

The reactor temperature control is a cascade control loop . The reactor temperature controller is cascaded to the inlet mixed phase temperature controller, which is then cascaded to the reactor feed furance firing control system. The reactor temperature controller has three modes of operation: normal control, backup control, and safety cutback control.

6.3. l.l First LCMAX Reactor Nonnal Control

The controlled variable for the reactor temperature controller is the average temperature calculated by the temperature surveillance program. The operator provides the set point. The operating parameters are defined as:

Variable

Average tempera hire controller normal operating range set point high limit deviation alann from set point total range

Inlet mixed phase temperature controller instrument range set point rate of change limits rate of change normal setting

Parameter

420 to 435°C 441 °C ±3°C 100 to 550°C

150 to 450°C 0.0 l to 4 °C per minute l °C per minute

NOTE: The inlet mixed phase temperahire controller set point rate-of-change limits can also be inte1preted as the average controller output rate of change limits because, under normal control, they are cascaded to each other.

Under normal operating conditions, a temperature difference of 48 to 56°C should exist between the first LCMAX reactor mixed phase inlet temperahire and the reactor average temperature.

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This temperah1re difference is monitored by means of a differential temperature indicator. The table below defines the alarm settings for the differential temperature:

Alarm Description Low-low differential Low differential High differential High-high differential

6.3. l.2

Alarm Setting °C 40 46 62 72

First LCMAX Reactor Backup Control

The control of the reactor temperature is critical to the operation of the plant. Therefore, the temperature calculation and control loop must be provided with a high degree of security. Modern DCS systems have redundant calculation and control modules. The reactor average temperature cascade control loop must reside in a redundant module, such that a failure of the module will not cause the reactor temperature control to fail. This means that the temperah1re surveillance program that calculates the reactor average temperahire used in control must reside in a redundant module.

Furthermore, if the reactor average temperahire calculation is not performed in the most reliable device of the DCS system, then a backup reactor temperature for reactor nonnal temperahire control must be generated (as per Section 6.2.3 .1) in the most reliable device of the DCS system.

6.3 .1.3 First LCMAX Reactor Cutback Control

The cutback control system manipulates the reactor feed tl1rnace outlet temperature controller set point rather than the mixed phase inlet temperature after detection of a malfunction. Refer to Section 6.6 for complete details.

6.3 .2 Second LCMAX Reactor Temperature Control

The reactor average temperature control is a cascade control loop. The second LCMAX reactor average temperature controller is cascaded to the inlet mixed phase temperature controller, which is then cascaded to the quench flow controllers.

6.3.2.1 Second LCMAX Reactor Normal Control

The controlled variable for the second reactor temperature controller is the average temperah1re calculated by the temperahire surveillm1ce progrmn. The operator provides the set point. The operating parameters for the second LCMAX reactor are the same as the first reactor and are defined in Section 6.3.1.1.

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The temperature differential alarm settings for the second LCMAX reactor are defined below:

6.3.2.2

Alarm Description

Low-low differential Low differential High differential High-high differential

Alarm Setting °C

17 22 34 40

Second LCMAX Reactor Backup Control

The control of the reactor temperature is critical to the operation of the plant. Therefore, the temperature calculation and control loop must be provided with a high degree of security. As stated previously, modem DCS systems have redundant calculation and control modules. The reactor average temperature cascade control loop must reside in a redundant module, such that a failure of the module will not cause the reactor temperature control to fail. This means that the temperature surveillance program that calculates the average reactor temperature used in control must reside in a redundant module.

Furthermore, if the reactor average temperature calculation is not performed in the most reliable device of the DCS system, then a backup reactor temperature for reactor nonnal temperature control must be generated (as per Section 6.2.3. l).

6.3 .2.3 Second LCMAX Reactor Cutback Control

The cutback control system manipulates the inlet mixed phase temperature controller set point after detection of a malfunction. For details , refer to Section 6.6.

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6.3.3 DAO LCMAX Reactor Temperature Control

The reactor average temperature control is a cascade control loop. The reactor temperature controller is cascaded to the inlet mixed phase temperature controller, which is then cascaded to the reactor foed furnace firing control system. The reactor temperature controller has three modes of operation: normal control, backup control, and safety cutback control.

6.3.3.l DAO LCMAX Reactor Normal Control

The controlled variable for the reactor temperature controller is the average temperature calculated by the temperature surveillance program. The operator provides the set point. The operating parameters are defined as:

Variable

Average temperature controller normal operating range set point high limit deviation alann from set point total range

Inlet mixed phase temperature controller instrument range set point rate of change limits rate of change normal setting

Parameter

430 to 442°C 444°C ± 3°C 100 to 550°C

150 to 450°C 0.0 l to 4 °C per minute l °C per minute

NOTE: The inlet mixed phase temperature controller set point rate-of-change limits can also be inte1preted as the average controller output rate of change limits because, under normal control, they m·e cascaded to each other.

The temperature differential alarm settings for the DAO LCMAX reactor are defined below:

6.3.3.2

Alarm Description

Low-low differential Low differential High differential High-high difierential

DAO LCMAX Reactor Back Control

Alarm Setting °C

55 60 77 87

The control of the reactor temperature is critical to the operation of the plant. Therefore, the temperature calculation and control loop must be provided with a high degree of security. Modern DCS systems have redundant calculation and control modules. The reactor average

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6.0 - 17

temperature cascade control loop must reside in a redundant module, such that a failure of the module will not cause the reactor temperature control to fail. This means that the temperature surveillance program that calculates the reactor average temperature used in control must reside in a redundant module.

Furthennore, if the reactor average temperahire calculation is not performed in the most reliable device of the DCS system, then a backup reactor temperature for reactor nonnal temperah1re control must be generated (as per Section 6.2.3 .1) in the most reliable device of the DCS system.

6.3.3.3 DAO LCMAX Reactor Cutback Control

The cutback control system manipulates the reactor feed furnace outlet temperature controller set point rather than the mixed phase inlet temperature after detection of a malfunction. Refer to Section 6.6 for complete details.

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6.4 Continuous Control Philosophy: Catalyst Bed Level Control Strategy

The reactor catalyst bed level is monitored and controlled by means of nuclear density detectors located at discrete points along the reactor. See P&IDs drawing BD-133337 and BD-133338 for details on density transmitter locations for 1 OO-R-10 l. The density detectors measure the radiation level which is transmitted through the fluid phase from a nuclear source contained in density detector wells inside the reactor. The denser the fluid phase, the less radiation is transmitted from the source to the detector. As such, the fluidized catalyst bed level can be distinguished from the gas/liquid mixture above it.

There are five density detectors per reactor and one nuclear source per detector. The sources are aligned with their respective density detectors such that they are at the same elevation from the reactor top tangent line (TTL). Initially, and until such time the catalyst reaches equilibrium loading, the detectors and sources will be located 2134 mm, 2 7 44 mm, 3049 nu11, and 3811 mm below the reactor TTL.

In response to a change in bed level, either above or below the control detectors, a signal is sent to either reduce or increase the set point of the recycle pump speed controller. As a result the variable frequency drive (VFD) output is adjusted to satisfy the desired recycle pump speed. Normally, the recycle pump speed is maintained at its desired set point through feedback of the measured pump speed into the VFD.

Alternatively, it is possible to control the recycle pump directly from the VFD output without feedback of the measured pump speed.

In the following control philosophy description, generic names are used for instrnment tag numbers as the control will be identical for all reactors .

6.4. l Normal Control

The catalyst bed level is non11ally controlled between the normal high and low-density detector elements located 2744 mm and 3049 n1111 below the reactor TTL, by automatically adjusting the reactor recycle pump speed controller set point using the DCS controller. If the bed level lies between the 2744 mm and 3049 mm detectors, no change is made to the speed controller set point, and the motor speed is controlled at its existing value. Should the bed level drop below the 3049 mm detector, the set point of the speed controller will be increased by a fixed increment immediately and at fixed time intervals thereafter, until the bed level is once again detected above this detector. Similarly if the bed level is detected above the 2744 mm detector, the set point of the speed controller is decreased a fixed increment in1111ediately and at fixed time intervals thereafter, until the bed level falls below this detector.

Should the bed level fall below the low-low detector located 3811 n1111 below the reactor TTL, the set point of the speed controller will be increased by a fixed increment (i.e. , normally two times the increment for the normal low level detector) and at fixed time intervals thereafter, until the bed level is detected above this detector.

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6.0 - 19

If, in the case of an upset, the bed level increases above the extra high level detector, located 2134 nun below the TTL, the magnitude ofreductions to the set point of the recycle pump speed controller will be increased and the frequency of reductions will be accelerated. The following table identifies the magnitude and frequency of speed adjustments initiated as a result of the bed level falling below the 3049 mm and 3811 mm detectors or rising above the 2744 mm and 2134 nun detectors.

Bed Level

Below 3811 mm detector

Below 3049 nun detector

Between 2744 mm and 3049 mm detectors

Above 2744 mm detector

Above 2134 mm detector

Magnitude of Change

+ 2

+ l

0

- 4

-60

Time Interval between Adjustments

(seconds)

60

60

60

10

Changes to the above time interval and RPM settings should be adjustable on the run, but under key lock for engineer access only.

The extra low-low level detector is located 8840 mm below the top tangent line. This detector does not initiate any actions, but is used for infonnation and guidance only. n: in the case of an upset, the bed level drops below this detector the operator should act to re-establish normal bed expansion as quickly as possible. Although this detector does not in itself initiate any actions, when the bed level is above the 8840 mm detector, inhibit logic will prevent the operator from increasing the speed of the recycle pump at a rate greater than 50 percent of the rate which the extra high level detector is capable of reducing the pump speed. If the bed level is below the 8840 mm detector, unrestricted changes to the pump speed can be made.

The presence or absence of the catalyst bed is detem1ined by whether the fluid density is above or below a specific value. This value will have to be adjusted during the detailed engineering phase to correspond to the actual densities that will exist within the reactor. The values used below are preliminary.

The maximum gas/liquid (two phase) density in the reactor is expected to be around 500 kg/m3.

The minimum gas/liquid/catalyst (three phase) density in the reactor is expected to be around 800 kg/m3

.

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Since the density cannot exist in the range of 500 kg/1113 to 800 kg/1113, the density will abruptly

increase from 500 kg/m3 to a value greater than 800 kg/1113 when catalyst is present and will drop from 800 kg/m3 to a value below 500 kg/m3 when catalyst is not present. A trip point somewhere between 600 kg/m3 and 650 kg/m3 on the analog density signal can therefore be used to positively identify the presence or absence of catalyst.

The above detection strategy determines the level of the catalyst bed and appropriate action is taken to raise or lower the bed levels such that it is between the 2744 mm and 3049 nun detectors.

The speed controller is used as the platfom1 from which the catalyst bed level control application sends its control signal output to the VFD speed controller. The speed controller output range is 0 to l 00 percent, which co1i-esponds to 500 RPM to 1780 RPM. The VFD controller will bring the pump RPM up to 500 when started, which corresponds to a 0 percent set point input from the reactor recycle pump speed controller.

The speed controller is to have three control modes, as defined below:

Auto

Semi-Auto

Mmrnal

6.4.1.l

The catalyst bed level control program is m full control of the speed controller set point.

The operator controls the set point of the speed controller but subject to ovetTide protection from faulty indication, high-high and high bed levels, and rate-of-change limits when raising the RPM when the bed level is above the 8840 nun detector.

The operator has full control of the speed controller output \Nith no ovetTide protection. This mode is not available to the operator except when the catalyst bed level control program automatically switches to it when a density detector fault has been detected. This mode cannot be left until the fault has cleared.

For full details on these three control modes refer to Tables 6.4.1-1.

Special Control Features

If the bed level exceeds the normal high (27 44 mm) or extra high (2134 nun) level detectors, the recycle pump speed is to be reduced regardless of whether the control system is in the auto or semi automatic control mode. In the semi-automatic mode, however, the pump speed is not automatically increased when the bed level is detected below the normal low (3049 nun) and low-low (381 l mm) level detectors.

If the control system was in the auto control mode and the catalyst level exceeded the normal high (2744 mm) or extra high (2134 nun) level detectors, and subsequently the operator placed

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6.0 - 21

the control system into the semi-automatic control mode, speed reductions would continue to be made until the bed level dropped below both these detectors. Under these conditions, the operator would be able to simultaneously reduce the pump speed. Operator speed adjustments would be additive to those of the bed level control program.

6.4.1.2 Mode Selection

The operator is allowed to select two modes, auto and semi-auto, \vhen conditions are normal.

The manual mode can only be selected by the bed level control program and only then if it detects ce1tain predefined faulty detector indications .

The bed level control program will override any attempt by the operator to select the manual mode and it will maintain the last mode (auto or semi-auto) the speed controller was in.

6.4. l.3 Control Mode Transfer from MAN to AUTO

When faulty density indication conditions are repaired, the program will only allow a transfer of mode from manual to semi-auto.

Once this mode transfer has been made, the operator is allowed to transfer to the auto mode to enable the bed level control program to take over foll automatic control of the catalyst bed level.

6.4 .2 Faulty Detector Indication

Capability to identify and take action upon detection of a faulty detector indication is required. Only the following faulty detector combinations need be considered:

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ACCORDANCE WITH INRITTEN PERMISSION OF


6.0 - 22

Table 6.4.2-1

Faulty Indication Low-Low Normal-Low Norm-High Extra-High Number 3811 mm 3049 mm 2744 mm 2134 mm

L H L L 2 L L H L 3 L L L H 4 L H H L 5 L L H H 6 L H L H 7 H L H L 8 H L L H 9 H L H H 10 H H L H 11 L H H H

"H" represents a high density reading or the presence of catalyst while "L" represents its absence. The extra low-low level detector (8840 nm1) is not to be included in the faulty indication detection methodology as it adds little to the evaluation.

In the case of faulty indications 1, 4, and 11 where it is assumed the low-low detector is in effor, the control system is to be maintained in the auto mode. Control actions for the n01111al low (3049 mm), n01111al high (2744 mm), and extra high (2134 nm1) level detectors are to be implemented as per the normal control logic .

Outlined below (and in Table 6.4.2-1) are the actions initiated should any of the remaining faulty indications (2, 3, 5, 6, 7, 8, 9, 10) be detected. Upon completion of the set of actions identified, the system is placed in and held in the manual mode. No further automatic actions are implemented. In the manual mode, the control system assumes complete control of the bed level and the high level oveffide protection is no longer in effect, unlike the semi-automatic oveffide mode.

There is no switching from one faulty indication to another, either during execution of actions or after completion. Thus only one set of actions are executed when a faulty indication occurs, and any further actions will be executed only if normal control has first been established.

Once the detector fault has been coITected, the operator sets the speed controller back to the semi-automatic control mode. From this point the system can then be returned to the automatic bed level control mode by the operator.

6.4.2. l F aultv Indication No. 2

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6.0 - 23

Should the normal high detector (2744 nun) indicate the presence of catalyst while the extra high, normal low, and low-low level detectors do not, a single 12 RPM reduction in the speed of the recycle pump will be made.

6.4.2.2 Faulty Indication No. 3

Should the extra high detector (2134 nm1) indicate the presence of catalyst, while the normal high, normal low and low-low level detectors do not, a single 60 RPM reduction in the speed of the recycle pump will be made.


If catalyst is detected at the extra high (2134 mm) and normal high (2744 mm) detectors, but not at the normal low and low-low level detectors, the recycle pump speed will be reduced 60 RPM inm1ediately and every l 0 seconds thereafter until one of the following conditions is met:

The extra high or normal high detector no longer indicates catalyst is present and a minimum of two cuts have been made.

A total of three cuts have been made.


If catalyst is detected at the extra high (2134 mm) and nomrnl low ( 3049 mm) detectors but not at the normal high and low-low level detectors, the recycle pump speed will be reduced 60 RPM immediately and every l 0 seconds thereafter until one of the following conditions is met:

The extra high or normal low detector no longer indicates catalyst is present and a minimum of two cuts have been made.



If catalyst is detected at the low-low (3811 nm1) and normal high (2744 nun) detectors, but not at the normal low and extra high level detectors, a single 60 RPM reduction in the recycle pump speed will be made.


If catalyst is detected at the extra high (2134 nm1) and low-low (3049 nm1) detectors but not at the normal high and normal low level detectors, the recycle pump speed will be reduced 60 RPM immediately and eve1y l 0 seconds thereafter until one of the following conditions is met:

The extra high or low-low detector no longer indicates catalyst is present and a

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6.0 - 24

minimum of two cuts have been made.



If catalyst is detected at the extra high (2134 mm), normal high (2744 mm), and low-low (3811 mm) detectors but not at the normal low detector, the recycle pump speed will be reduced 60 RPM inunediately and every l 0 seconds thereafter until either one of the following conditions is met:

The extra high or normal high detector no longer indicates catalyst is present and a minimum of two cuts have been made.

A total of four cuts have been made.

6.4.2.8 Faulty Indication No. l 0

If catalyst is detected at the low-low (381 1 nun), normal low (3049 mm), and extra high (2134 mm) detectors but not at the nonnal high detector, the recycle pump speed will be reduced 60 RPM immediately and every l 0 seconds thereafter until either one of the following conditions is met:

The extra high or normal low detector no longer indicates catalyst 1s present and a minimum of two cuts have been made.

A total of four cuts have been made.

6.4.2.9 Alarm Functions

The following values are alarmed:

An extra low-low alarm is activated if the bed level drops below the 8840 mm detector.

A low-low alarm is activated if the bed level drops below the 3 811 nun detector.

If the bed level remains above normal high (2744 nun) detector after tlu·ee consecutive reductions of 4 RPM each, an alann sounds .

An extra high level alarm is activated if the bed level rises above the 2134 nun detector.

If the bed level remains above extra high detector after three consecutive reductions, an alarm sounds .

If the pump speed controller is set to manual mode, an alarm is activated.

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6.0 - 25

If the pump speed controller is set to semi-automatic mode, an alann is activated.

An alarm is activated upon detection of a faulty detector indication combination.

CONFIOENTIAL

PROPERTY OF CLG TO BE REPRODUCED, AND USED_ ONLY IN

ACCORDANCE WITH INRITTEN PERMISSION OF


6.0 - 26

6.5 Furnace Control

There are four fired heaters: the Reactor Feed Furnace (100-H-101), the DAO Feed Furnace (100-H-102), the Reactor Feed Oil Furnace 612-F-201 (Train 2), the Atmospheric Tower Feed Furnace (100-H-301), and the Vacuum Tower Feed Furnace (100-H-401). Each heater is designed to fire fuel gas.

6.5 . l Firing Control

All of the heaters are designed for firing foel gas. The Detailed Engineering Contractor will develop the control scheme for fuel firing controls.

6.5 . l.l Fuel Gas Firing

A temperature controller that resets the firing rate controls the coil outlet temperatures of the furnaces. The Detailed Engineering Contractor shall develop firing control logic with input from the heater vendor.

6.5.1.2 Burner Management System

The heaters shall be furnished with a burner management system, which will be designed by the Detailed Engineering Contractor.

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6.6 Continuous Control Philosophy: Reactor Automatic Cutback and Depressuring Aimlication

The objective of the automatic cutback control system is to bring the reactors to a safe operating condition after an upset while minimizing pressure and temperature flexes. To achieve this objective, a cutback control system is required that manipulates the set points of temperature, flow, and pressure controllers to achieve safe operating states after the detection of upsets or malfunctions in the process. The cutback control system in certain cutback applications will initiate the interlock system to shut valves. The cutback control system is designed to operate as an integral part of the distributed control system and safety interlock system, and must be able to operate within the constraints imposed by the safety interlock system.

The LCMAX Unit is set up such that both LCMAX reactors must be operational. Since the unit can only operate with both reactors on stream, any condition detected which can cause a cutback will bring both reactors to a standby state. The applications which detect a cutback and those that control a cutback must be implemented such that a maximum level of security can be achieved.

6.6.1 Description

The cutback control system detects malfunctions and ramps the set points of critical process variables to safe standby states. The cutback control system detects malfunctions from plant instrumentation, the interlock system and from the temperature surveillance logic. Upon detection of a malfunction, the cutback control system ramps the set points of process controllers to a safe standby condition. The cutback applications are defined on P & I drawings.

The controllers used in the cutback control are part of the continuous control logic in the digital control system (DCS). They perfonn normal control until a malfunction is detected. A cutback control logic program that resides in the DCS is constantly executing and monitors the status of the malfunctions. When the program detects a malfunction, it decides which cutback action to perform and then manipulates the set points of the above controllers in a defined sequence to a safe standby state. In effect, the program perfonns like interlock logic; however, it is an integral part of the DCS control system. Since the program is part of the safety system of the reactor control, it must have the same security as the other DCS control systems. This means it must be part of the redundant security of the DCS.

A cutback control action can be initiated by one or more possible malfunctions. These malfunctions can occur one at a time, simultaneously, or in series. If two or more malfunctions initiate the cutback action, then the cutback program must decide which of the set points calculated from the ramp and hold time to output to the controller. With the goal to get to the target set point from the current operating set point in minimum time, the program selects the setpoint that will result in the fastest ramp to the new set point.

In the event a cutback controller (excluding controllers that are in NNF service and are normally in manual mode) is in manual dming a cutback, the cutback program will place the cutback on

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6.0 - 28

hold and initiate an alarm to the operator that the cutback action is not being taken.

6.6 .2 Malfunction Detection and Actions

The cutback control program runs with an execution period of 5 seconds or less. For each cutback action, the program stores the target set point, the ramp time, and the hold time. When one or more malfunctions occur, the program, at each execution interval, calculates a new ramp set point for each malfunction. The cutback program then selects the set point for the cutback controller that yields the greatest ramp rate. In the event multiple malfunctions occur that result in conflicting target set points, the cutback program will select the set point that leads to the safest operating condition.

Before any of the malfunctions are detected, a master enable/disable (HS-XXXX) switch is checked to determine if the cutback control program is to execute. The status of each malfunction (active or inactive) must be displayed in the DCS.

6.6 .3 Annunciation m1d Messages

For each cutback action, the cutback control program sends the following message to the DCS alann printer:

Cutback action N-XXXX initiated Cutback action N-XXXX tenninated Cutback action N-XXXX disabled Cutback action N-XXXX completed Cutback action N-XXXX not started because controller yyyyyyyy is in manual

(Where XX.XX is the number of the cutback action being referred to and yyyyyyyy is the specific controller that is in manual mode.)

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6.0 - 29

6.7 Emergency Shutdown System Philosophy

The emergency shutdown logic will automatically shut down individual pieces of equipment in the event that they exceed a predetermined safe operating limit or exceed predetermined acceptable process requirements.

Since all individual pieces of equipment have full measuring capabilities of all their process variables, the logic system will shut them down if the process conditions exceed their own requirement.

For example, on loss of the feed oil pumps, the feed oil heater is not automatically shut down. The heater logic has low limit inputs from the ±low measurement to the heater and it will shut down on low flow measurement.

Plant emergency cutback and/or depressurization is performed by the DCS or SIS, whichever system is appropriate for the necessary action. The unit perfonnance is monitored by the measurement of a number of key elements in the unit. Examples of this are high-high or high reactor temperatures, temperature maldistribution in the reactors, loss of recycle gas, loss of oil feed to the unit, and loss of internal recycle pumps.

On malfunction of any of these, a unit cutback/depressurization is automatically initiated and carried out in the appropriate system. The cutback involves the ramping of set points of controllers, mode changes on controllers, valve trips and equipment shutdown. All of these sections involve a controlled and time dependent set of actions on devices which reside either in the DCS or SIS system.

The automatic actions take the unit to a safe standby condition. A complete shutdown from this point on is an operator decision and is manually perfonned by the operator.

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6.0 - 30

6.8 Interface with DCS

From the SIS only one-way software c01mnunications to the DCS shall be allowed. All shutdowns shall be performed only via the SIS system.

For signals such as equipment shutdown indication and alarm in the DCS, where the signals originate in the SIS, only a software link is envisaged, as no secondary actions will be required, and other process alarms will come in through an independent path to signify the loss of a piece of equipment. Any switches in the field which are wired to the SIS to cause an equipment trip and are required for alarm purposes in the DCS are connected by the software link.


TO B E REPRODUCED, AND USED_ ONLY IN

ACCORDANCE W ITH WRITTEN PER MI SSION OF


APPENDIX: DCS SYSTEM REQUIREMENTS SPECIFICATION

1.0 Purpose 2.0 General 3.0 Display Equipment Definitions 4.0 Display System Configuration 5.0 Process 1/0 Equipment 6.0 Sequencing and Interlocks 7 .0 Applications Programs 8.0 System Communications 9.0 Primary Power 10.0 Grounding


TO BE REPRODUCED, AND USED_ ONLY IN

ACCORDANCE W ITH WRITTEN PER MI SSION OF


1.0 Purpose

The intent of this document is to provide special control system (DCS) requirements and guidelines related to the LCMAX Residue Hydrocracking Plant. The information contained herein should be incorporated in a complete tlmctional, qualitative, and quantitative distributed control system specification suitable for quotation.

2.0 General

The DCS shall perform the monitoring and advanced control functions necessary to pennit normal plant operation independently of higher level devices .

3.0 Display Equipment Definitions

Control Center

Console

Peripherals

Console Electronics

Operator Work Station

Engineer' s Work Station

4.0 Display System Configuration

Centralized area for remote plant operation.

Color CRT monitor and keyboard combination with a dedicated or shared display microprocessor.

Printers, screen copiers, data drives, hard pen recorders, annunciators, switches, status lamps, etc.

Microprocessor-based electronics providing display generation, online configuration, keyboard and peripherals interface for one or more consoles.

Control center cluster, consisting of one or more operator consoles and associated peripherals.

Engineers console, console electronics and peripherals as required to allow system monit01ing, and oft1ine configuration at an area other than the control center.

The suggested minimum operator work station arrangement for this area is:

* Operator Consoles (* quantity to be determined during detailed engineering) 2 P1inters (1 Alarm, l Report) ... Auxilia1y Stations (Annunciator, Switch) (* quantity to be detennined during detailed enginee1ing) 2 Work Table (Optional)

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2 Screen Color Copier (multi-channel) .

All operator consoles within an operator work station should have mutual access to the smne data base mid one another's displays.

Peripheral Eguipment

The LCMAX Unit requires some special peripherals installed within the auxilia1y section of the operator work stations. These include selector, push buttons, dedicated alarms, and status lamps associated with motors and the safety shutdown interlock systems.

Engineer' s Work Station

It is reconunended that an engineer's work station be included in the DCS scope of supply to permit ot11ine configuration activities in an area other than the control center. Peripherals such as a system printer and magnetic storage drives should be included with this work station. This work station can be common to the plant.

5 .0 Process I/O Equipment

Definitions

Controller

Data Acquisition Drive

Controller Distribution

Microprocessor-based electronics providing control algorithm execution and process I/O interface functions.

Microprocessor-based electronics providing processing I/O interface for monito1ing only functions .

The DCS shall utilize a philosophy of multiple, independent controllers (i .e., distributed control). The use of a single large capacity controller (regardless of backup philosophy) is not acceptable.

Controller Peer-to-Peer Communication

Algoritlm1 linking shall be done internally by software assigmnent. A m1mmum of 16 algo1ithms shall be linkable in this manner within any single controller. In the event that the selected DCS controller processes fewer than 16 algorithms, the system should provide true peer-to-peer communication to facilitate the required linking. For true peer-to-peer communications, there should be no limitation in tracking and initialization between blocks.

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Redundancy

Automatic controller backup must be included as a DCS requirement. The type of controller backup employed can be either dedicated or shared provided that the method used has demonstrated reliability.

Data acquisition devices do not require redundancy. (All inputs used in control applications require redundancy.)

System power supplies should also be backed up.

Trending Trending should be available for all control and data acquisition inputs .

Alarming All data acquisition points and controllers must be equipped with process variable high and low alarms.

Totalizers The DCS must be capable of totalizing both analog and pulse flow measurement inputs.

Recorders The DCS shall be capable of supporting software assignable pen recording of any process variable in the DCS . The quantity ofrecorders shall be specified by the client.

Historical Trending The DCS shall provide historical trending capable of storing 1 month of data with a sample time of 10 minutes. Sizing should be done based on historical trending specified on P&I drawings with 20 percent spare capacity. The DCS shall be capable of storing data to a permanent storage media to permit analysis at a later date.

6.0 Sequencing and Interlocks

The LCMAX process requires a significant amount of sequences, batching, cutbacks and interlocks be implemented by the control system. These control functions shall be implemented in combination in the DCS and progranm1able logic controller. The general guideline for the distribution of these functions is as follows:

DCS Any function/logic that involves the manipulation of controller modes, set points, or outputs shall be implemented in the DCS using a redundant control/programming device.

SIS Any safety interlock function/logic that involves discrete logic, such as on/off or open/closed, shall be implemented in the SIS. This includes the manipulation of motors,

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ACCORDANCE WITH WRITTEN PERMISSION OF CHEVRON LUMMUS GLOBAL

on/off valves, solenoid valves, etc. Conununications between the DCS and PLC shall be tlu·ough a field proven, redundant serial interface. It shall be possible to communicate both discrete and analog data tlu·ough this interface.

7.0 Applications Programs

There are applications in the LCMAX Reside Hydrocracking Plant that reqmre complex calculations and control logic to execute. These applications include: the temperature surveillance calculations, the cutback control, and the level control. To execute these applications requires a programming language such as Fortran, Basic, C, or similar type languages. And, because of the critical nature of these applications, they must mn in redundant DCS modules .

As specified in this write up, the temperature surveillance application has a large amount of data handling, data checking and calculation. This can best be achieved \vith a programming language.

The cutback control has logic checking and some calculations that can either be done with a progranm1ing language or a batch sequence language as specified in Section 6.6 sequence and interlock.

The level control requires detection of a logical digital pattern which can be done with a progranuning language or a batch sequence language as specified in Section 6.6 sequence and interlock.

The level control requires detection of a logical digital pattern which can be done with a progranm1ing language or a batch sequence language as specified in Section 6.6 sequence and interlock.

8.0 System Conununications

The DCS conununication system shall utilize a redundant conununications network utilizing dual data buses and fully redundant conmmnication electronics. Communications cabling shall be routed in physically protective conduit with sufficient shielding and physical separation from electrical noise sources. The dual data buses should be routed separately to eliminate the possibility of simultaneous accidental damage to both buses.

9 .0 Primary Power

The DCS, host computer, and related instrument systems should receive prima1y power from a dedicated power supply and distributed system. This system should include a batte1y supported unintermptable power supply and an isolation transfonner that delivers filtered and surge protected p1immy power regardless of the source. The degree of power filtration required

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should be based on the published power quality requirements of the worst case user.

l 0.0 Grounding

The DCS related grounding systems shall be designed to minimize ground noise transmission from higher voltage equipment and switch gear, provide a low resistance path between DCS equipment to ea1th, and provide lightning surge protection and safety grounds.

For DCS systems utilizing system cabinets as reference, the following grounding systems are required.

DCS System Grounds Signal Reference Grounds DC Power Supply Conm1ons Signal Cable Shields Communication Cable Shields DCS Related AC, and Cabinet Safety Grounds

Lightning Grounds

Host Computer Reference Grounds.

Each of the above grounding systems requires separate connections to a dedicated section of sub-grid of the plant ground system.

The selected DCS Vendor should be consulted concernmg the grounding scheme pnor to finalizing.

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7.0- SAFETY, HEALTH, AND ENVIRONMENT

Introduction

This section contains an overview discussion of imp01tant safety, health, and environmental items. An expanded discussion will be presented in the Process Manual.

The materials handled in the Unit are flammable and some are toxic. However, they are similar to those encountered in any refining unit and are paiticularly like those encountered in any hydrogenprocessing unit. The following should be kept in mind:

The reaction section operates at a relatively high pressure that mcreases the possibility of a hydrogen leak.

Hydrogen has a very wide range of "explosive limits." Concentrations (by volume) of 4-75% hydrogen in air can explode. Also, hydrogen' s minimum ignition energy is lower than for hydrocarbon gases.

The primary operation produces large quantities of H2S, which is a toxic material. Thus, essentially all gas streams and most liquid streams will contain H2S in varying amounts.

The following comments are intended to supplement, but in no way to conflict with ex1stmg refinery safety regulations. They are also intended to provide more detailed information concerning the specific hazards discussed above.




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7.1 Safety

7.1.1 Safety Design Codes and Standards

In the design of the Residue Hydrocracker, U.S. industrial codes, standards and generally accepted recommended practices regarding process safety have been followed. The major codes, standards, and recommended practices that have been followed are outlined below along with any specific exceptions that have been taken. The selected detailed design contractor is responsible for any local codes and regulations.

7.1.1.1 American Society of Mechanical Engineers (ASME)

The ASME Boiler and Pressure Vessel Code Sections I and VIII, is generally followed for the design of emergency relief devices for vessels within the jurisdiction of the mandato1y parts of the Code.

Piping design is in accordance with ASME B3 l .3, Process Piping.

7.1.1.2 American Petroleum Institute (API)

The provision of overpressure protection systems shall generally follow the recommended practices and standards of the API as given in the following publications:

• Recommended Practice 520, Sizing, Selection, and Installation of Pressure-Relieving Devices in Refineries; Part I - Sizing and Selection, Pm1 II - Installation.

• Recommended Practice 521 , Guide for Pressure-Relieving and Depressuring Systems.

• Standard 2000, Venting Atmospheric and Low Pressure Storage Tmtlcs

It is pointed out, however, that there are a few exceptions that are recommended per CLG's practice as given below:

I. API-RP-521 recommends that the low pressure side of heat exchangers be provided with overpressure protection for a tube rupture scenario only if the design pressure of the high pressure side exceeds the test pressure of the low pressure side. Instead, in compliance with ASME Code, overpressure protection is provided on the low pressure side if the normal operating pressure on the high pressure side exceeds the design pressure on the low pressure side. However, consistent with API recommendations, both transient shock and steady state conditions should be considered in the design of overpressure protection byDDC.

2. API-RP-521 recommends that redundant back flow prevention (e.g. , two check valves) be provided on the discharge side of a pump if cessation of flow and failure of a single check valve result in a suction side pressure exceeding test pressure. Instead back flow isolation (chopper valve) and check valve are provided if the suction pressure can exceed




7.0 - 3

the design pressure or a relief device is provided on the suction system to protect against overpressure due to back flow.

3. API-RP-521 states that a commonly accepted response time for operators to take action that can reduce the required relief capacity of overpressure protection systems is between 10 and 30 minutes depending on the complexity of the plant. Instead the design relief capacity of overpressure protection systems is not reduced on the basis of operator corrective actions.

4. API-RP-521 recommends that consideration be given to the possible failure of a control valve open while the by-pass valve is fully or partially open. As long as the design intention is to only use the bypass in place of the control valve, the following rule is followed instead for determining the maximum flow through a control valve station: the maximum flow is the flow produced by either the control valve wide open (with the bypass/spare control valve completely closed) or the bypass/spare control valve wide open (with the control valve completely closed).

7 .1 .2 Process Safety System Design Basis

7.1.2.1 Overpressure Protection Systems

Protection against overpressure of pressure vessels under the jurisdiction of ASME Code shall be provided by adequately sized emergency relief devices . Relief device design is based on those considerations given below.

1. All singular failure modes that can result in overpressure are considered. Generally, designing for unrelated, simultaneous causative failure events (i.e. , "double jeopardy") is not necessary when the individual failure rates are very low and the failures are overt (i.e., self-revealing). If a failure is covert (i .e. , non-revealing) and can persist undetected for a considerable period of time, such a failure is considered concurrently with other failures. Generally, the failures considered can be categorized as equipment breakdown, control system failure, outage of supporting utility systems, operator error and external fire exposure.

2. Safety interlock systems based on automatic controls and instrumentation are usually not considered as a substitute for adequately sized emergency relief devices nor are interlocks usually used to reduce required relief capacity. The design of this system has to be further reviewed at the Hazop/Hazan stage of detailed design with CLG participation.

3. Equipment is generally specified with suitable design pressure to withstand the maximum pressure resulting from feeding pump shutoff. This approach eliminates the need to size relief devices for this situation and avoids the discharge of liquids into the flare system. Exceptions to this approach are possible if the higher design pressure required significantly increases equipment cost, for e.g. , high pressure feed oil pumps, etc . In this case, the system is designed to withstand shut off pressure up to the isolation valve and downstream of it has an open path to a relief device.




7.0 - 4

4. The basis for the sizing of individual relief devices are presented on the relief summary given in Volume III. While these data sheets identify all pertinent failure scenarios, it is pointed out that the relief rates of some scenarios cannot be definitively determined at this time due to insufficient information. This information should be developed or confirmed by the DDC during detailed engineering. Such information includes, for example, control valve sizes (full throat Cv) and definition of fire zones I estimation of fire relief loads.

Definitive total cumulative relief flow rates from the Residue Hydrocracker have not been developed for scenarios involving the discharge from multiple relief devices. Such scenarios generally result from large scale common mode failures such as loss of utilities or fire exposure. A summary of the flare relief loads is presented in Volume III and some general guidelines as to how to estimate the cumulative loads are shared on a "for information only" basis with the Owner. It is the responsibility of the Owner/DDC to develop the required data for these scenarios based on specific refinery location considerations. In general, flare load reduction instrnmented mechanisms are not used in the development of this EDP. Owner/DDC may further study this aspect.

5. As required to ensure the required plant on-stream factor, certain safety relief devices have been provided with an installed spare. These safety relief devices are provided with inlet and outlet block valves to allow the removal of one safety relief device at a time for maintenance while the protected process equipment remains in service. The safety relief valves remaining in service provide the total emergency relief capacity required. To protect against inadvertent isolation of a safety relief device, a locking strategy is illustrated on the P&ID's for the inlet and outlet block valves. DDC to review the safety valve sparing and finalize the sparing philosophy of the PSV s with the Owner.

For safety relief devices that are not spared, a locked block valve is typically provided at the relief device outlet only. This isolation strategy will only allow maintenance to be performed after the protected process equipment has been taken out of service. The outlet block valve serves to allow safety relief device maintenance to be perfonned without necessitating shutdown of the flare system. For safety relief devices discharging to atmosphere, no block valve is provided on the outlet side.

Generally, block valves have not been provided in the relief path between interconnected pressure vessels protected by a conunon safety relief device. However, where a block valve has been provided, a lock has been included to ensure that the block valve cannot be closed inadvertently. Such a block valve cannot be closed until all sources of overpressure affecting protected equipment are properly isolated.

It is the responsibility of the DDC and Owner to ensure that the above safety relief device isolation strategies do not violate pressure vessel regulations and plant safety guidelines and plant insurance norms at the site. It is the responsibility of Owner to develop and enforce administrative procedures governing the locking and unlocking of block valves




7.0 - 5

that can isolate safety valves so that adequate overpressure protection is provided at all times while process equipment is in service.

6. It is CLG practice to provide overpressure protection on the low pressure side of heat exchangers for a tube rnpture if the operating pressure on the high pressure side exceeds the design pressure of the low pressure side. As advised in API-RP-521 , both steady state and transient conditions need to be considered. Severe transient overpressure may occur on the lower pressure side when high differential pressure exists, and the high pressure fluid is largely a vapor flowing into a low pressure side that is liquid-filled. In such cases, relief may be required using rupture disks located on the exchanger and sometimes on the low pressure side piping also. In some situations, rupture disks will not adequately limit low pressure side pressure transients, and the design pressure of the lower pressure side may have to be increased. Design approaches to protect the low pressure side from transient overpressure should endeavor to limit the peak transient pressure to the temperature corrected test pressure.

The disposition of relief occurring during a tube rupture is often complicated when the high pressure fluid is a hydrocarbon and the low pressure side fluid is steam or cooling water. Normally, the safety relief device on the steam or cooling water side would be discharged to atmosphere. However, during a tube rupture, hydrocarbon liquid and/or vapor could be discharged possibly resulting in a fire or flammable vapor cloud explosion hazard. In this situation such relief has been routed to the flare if flammable liquid or heavy vapor could be discharged. If the hydrocarbon is a light gas, discharge to the atmosphere can be considered.

It is the responsibility of the DDC to ensure that any emergency discharge of light hydrocarbon vapor to atmosphere be located at an adequately elevated point so that the hazard of a flammable vapor cloud will not jeopardize personnel safety. It is recommended that suitable hazard analysis be performed by Owner/DOC to determine a safe discharge location.

7. With regard to overpressure of air coolers during fire exposure, it is realized that large relief loads may be generated due to the large heat transfer area that can be exposed to fire heat input. It is CLG practice to consider fire exposure to air coolers if the bundle elevation is less than 7. 6 meters above a potential pool fire level. Fire exposure is not considered if the bundle elevation exceeds 15 .2 meters above a potential pool fire level. For bundle elevations between 7.6 and 15.2 meters above a potential pool fire level, fire exposure is not considered if the fans are automatically shut down using a passive switch (e.g. , fusible link or wire) - DDC to consider this suggestion on a case by case basis. Fan shutdown stops the fire heat transfer rate due to fan draft. Such switches might be considered by the DDC for all air coolers elevated between 7.6 and 15.2 meters above a potential pool fire level to manage potentially large relief loads to the flare system. If shutdown switches are not provided, then adequate relief may be required for fire exposure.


TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE VVITH W RITTEN PERMISSION OF


7.0 - 6

In general, the approach to overpressure protection of liquid-filled equipment containing heavy hydrocarbons (e.g. , atmospheric resid, vacuum resid) has been to minimize the likelihood of relief by designing to contain rather than relieve overpressure. This approach has been taken to avoid the relief of heavy liquids into the flare system.

In such situations, it has been possible to eliminate all causes of overpressure with the exception of fire exposure during which only the resulting liquid thermal expansion has been chosen as the basis for sizing the safety relief device. The discharge of vapor is not considered credible since the temperature required to vaporize these heavy liquids at relief set pressure is so high that equipment failure will result from overtemperature. Since the total amount of liquid discharged due to thermal expansion is small, the safety relief device discharge has been routed to a grade-level containment sump to avoid pocketing the discharge piping. The DDC should locate and design the sump to avoid personnel exposure to high temperature liquids.

8. While most emergency relief streams to the flare are vapors, there can be liquid and two phase, liquid-vapor discharges. The DDC shall normally ensure that all safety relief devices are suitably elevated so that the safety relief device outlet and associated discharge piping will be free-draining to the flare header. If this is not possible and the relief device discharge must be pocketed, then suitable connections shall be made at the low point to allow draining of any collected liquid.

All sections of the flare system where liquids may be present should be winterized by the DDC to avoid potential freezing that could jeopardize plant over-pressure protection. The DDC should also provide suitable liquid disengaging facilities in the offsite flare system to prevent liquids from being discharged into the environment via the flare stack.

7.1.2.2 Safety Interlock Systems

Safety Interlock systems are typically used to prevent major process operating upsets from threatening the physical integrity of process equipment usually by mitigating the extent of pressure and/or temperature deviations. As stated previously, instrumentation-based interlocks are usually not used in place of emergency relief devices or to reduce the required relief capacity. Such interlocks are nevertheless desirable to reduce the likelihood that an emergency relief device will be activated. It is the responsibility of DDC I Owner and or an Owner nominated Agent to develop the details of such SIS systems and determine the Safety Integrity Levels (SIL) and develop a system definition.

Safety interlock systems are provided to protect against temperature excursions outside of the mechanical design envelope of process equipment, for e.g. , reactors. Such systems typically institute system shutdown. Standards of the ISA and IEC provide general requirements for safety instrumented systems. CLG, Chevron and general industty experience has been referenced in the development of the reactor cut back and emergency depressuring system definitions. The magnitude of the consequences of interlock failure should be considered by DDC when determining the degree of reliability required. For critical interlocks that protect against loss of containment incidents with the potential for human injury or fatality, suitable instrument




7.0 - 7

redundancy should be provided by DDC. Critical alanns and interlocks are independent from control instrumentation.

7.l.2.3 Inventory Isolation

It is CLG's practice to provide a means to remotely isolate process material inventories where appropriate. Generally, inventory isolation takes the form of a remotely operated valve between the material inventory and a likely leakage point such as a pump seal, a flow sight glass, expansion joint, etc. Such an isolation valve is provided where the consequences of a leak are significant. Depending on fluid properties, the consequences may be a toxic material exposure, vapor cloud explosion or a liquid pool fire.

The application of remote isolation valves is justified on a case by case basis . The parameters involved in this decision include:

• Magnitude of fluid invent01y • Fluid phase • Liquid vapor pressure at process conditions • Fluid toxicity, reactivity and flammability • Potential leakage rate

The most common application of inventory isolation is the provision of a remotely operated valve on the suction side of a pump to protect against catastrophic failure of the seal. This failure is considered credible even for double mechanical seal arrangements . Alternatively, sealless pump designs may be considered to manage this risk.

Where remote isolation valves are provided to isolate potential leaks at pumps and compressors, the DDC should provide leak detection systems that alarm locally and in the control room so that the operator may respond in a timely fashion.

7. l.3 Process Hazards and Safeguards

The major cause of loss of containment of piping mid pressure vessels is operation outside of established mechanical design limits of temperature, pressure and in some cases fluid prope1ties. Initiating events leading to operation outside of design limits include:

• Instrumentation Failure • Utility Outage • Operator Error • Equipment Failure (e.g., rotating equipment trip offline) • External Fire

Improper installation/maintenance cm1 also result in equipment failures.

The risk of loss of containment is managed by a combination of the following :




Alanns and Emergency Procedures Interlock/Trip Systems Robust Mechanical Design Remote Isolation

7.0 - 8

Selection of Fail Safe Positions for Control Valves H2S Detection and Monitoring Ine1i Gas Blanketing Emergency Relief and Flaring Depressurization Emergency Power Diverse Drives on Cooling Systems and Other Critical Rotating Equipment Careful Operation Preventative Maintenance Fire Detection and Fire Fighting

The detailed design contractor may need to provide additional process safety systems to satisfy local safety regulations .

Major process hazards and safety systems provided are discussed briefly below. See the P&ID's and cut back interlocks for details .

7.1.3.l Feed Surge Drum

The major hazard in this area is a liquid pool fire that could result from a spill of a portion of or the entire hydrocarbon inventory in the Feed Surge Drum. The most likely cause of loss of containment is a seal failure at the Feed Pumps. To manage this risk, remote isolation valves are provided in the suction lines to these pumps. Upon closure of these valves, the pumps are shut down automatically via an interlock. To mitigate the back flow of high pressure pump discharge during a pump trip that could overpressure the suction system, redundant check valves and remotely operated I automatic isolation valve (Chopper Valve - l/i tum quick closing ball valve closing in less than l second) are provided in the discharge lines.

Overpressure protection of the Feed Surge Drum is provided by safety relief valves that are routed to the flare system. A high-high level alarm is provided for each drum to minimize the likelihood that liquid will overflow to the flare system in a blocked outlet situation or a failure of the level control system.

7.1.3.2 Feed Furnaces

On the process side of the Feed Furnace, the greatest hazard is potential coil failure due to excessive temperature that can result fi:om low feed oil flow or excessive firing rate. To protect against this potential hazard extra thick stainless steel coils are used in the heater, coil high "skin" temperature alanns and a trip system that shuts off the heater foel on low oil feed flow or low feed gas flow. To detect a low flow situation, low flow alarms are provided for oil flows to each heater coil. Low-low flow of oil to each heater coil is alarmed and results in a heater shutdown.




7.0 - 9

Excessive firing rate is detected by a high temperature alann on the firebox. High-high temperature alarm in the outlet of any one of the heater coils initiates heater shutdown. Coil skin temperature is also monitored and high temperature alarmed at selected points.

If a coil failure occurs, the flow of process liquid into the firebox can be mitigated by rapid isolation of the process side of the heater. This can be accomplished on the inlet side by closing the control valves in the oil feed lines and shutting down the Feed Pump. After feed and fuel gas are securely isolated, snuffing steam may be injected if necessaiy to extinguish burning oil on the floor of the heater. Coil overpressure protection is provided by safety relief valves that discharge to the Feed Surge Drum.

Typically, steam is superheated in a convection section coil. This coil is suitably designed so that failure due to over-temperature will not occur if steam flow ceases. A low flow alarm and a high outlet temperature alarm are provided to warn of high coil temperature. Coil overpressure protection is provided via a safety relief valve that discharges to atmosphere.

The principal hazard on the heater firebox side is potential deflagration. This hazard is most severe during light-off of the heater particularly when the heater is cold. Deflagration may occur if a flammable mixture exists in the firebox upon light-off. This condition may be due to improper isolation of fuel gas or insufficient air purge of the firebox. To prevent deflagration during light-off~ strict adherence to light-off procedures is necessary. Fuel gas must be securely isolated via redundant isolation valves and atmospheric vent, and the firebox adequately purged to ensure that a flammable mixture doesn ' t exist. Before light-off of the first pilot, the firebox should be tested with a portable analyzer to ensure a nonflammable condition.

Once the heater has been safely lighted off and is operating at normal temperature, the risk of deflagration is greatly reduced. However, there is a hazard of firing the heater with insufficient air. While this usually doesn' t result in deflagration, the liberation of unburned fuel can result in destructive afterburning at the heater stack. If a fuel-rich situation is corrected by the rapid admission of air, there is a hazard of an accelerated burning rate that may cause a positive pressure transient in the firebox.

To avoid this situation, safeguards are provided to protect against firing with insufficient combustion air. These include continuous monitoring of the flue gas oxygen concentration and a mechanical minimum position stop on the stack damper. Should an excess fuel condition develop, the fuel firing rate should be reduced immediately to establish the normal excess air level. The fuel firing rate must not be increased until the proper air flow has been restored.

Burner firing instability can also lead to potential fuel rich conditions in the firebox. This can occur due to fuel gas pressure at the burner that is outside of the burner' s tested stability limits or the presence of liquid in the fuel gas. Safeguards that address this include automatic burner fuel gas isolation based on low-low burner pressure, low-low pilot pressure, or high-high level in the fuel gas KO drum. If needed, based on burner stability tests, the DDC shall provide a heater trip on high-high fuel gas pressure.




7.0 - 10

During heater decoking, plant air is injected along with steam into the heater coil. To avoid inadvertent addition of air during normal feed processing, blinds and swing elbows are used to isolate plant air from the heater coils.

7.1.3.3 Reactors and Interstage Separator

The predominant hazard in the reactor system is the elevated operating pressure and temperature conditions in conjunction with large equipment inventories. In addition, hydrogen sulfide is present at concentrations exceeding the lethal threshold. The greatest threat to reactor mechanical integrity is overtemperature from uncontrolled exothermic reaction in reactor due to faulty temperature control, insufficient quench, or flow maldistribution in the catalyst bed which can lead to localized overtemperature or "hot spots". To maintain stable temperature control in the event of thermocouple failure , the average signal of several thermocouples is used as input to the temperature controller. Temperature throughout the reactors is monitored by an extensive array of temperature indicators provided with high temperature alarming. See the description of the reactor surveillance system provided in this EDP Volume I, Section 6.

To protect against temperature excursions outside of equipment mechanical design limits, an instrument-based system is provided to automatically implement process operating changes that will mitigate the temperature deviation. This "cutback/depressuring" system responds in a stepwise fashion depending on the degree of severity of the temperature excursion. Initial response actions focus on process changes that will mitigate the temperature rise. If required, subsequent actions include controlled depressuring to ensure vessel integrity at the higher temperature. A detailed description of the cutback depressuring system is provided in this EDP.

Depressuring is a required response not only to process-driven over-temperature but to other failure scenarios as well such as external fire exposure. Depressuring can also be used to mitigate the rate of an accidental liquid or vapor leak. While the cutback depressuring system automatically effects depressuring for process failures , depressuring for fire exposure and leak mitigation is activated manually.

To ensure reliable process control and minimize the likelihood of control system failure causing system overpressure, redundant transmitters, alarms and control valves are provided for differential pressure control and Interstage Separator level control. Control valve and transmitter switching can be accomplished rapidly from the control room by means of hand switches and remotely operated isolation valves .

7.1.3.4 Reactor Effluent Separation and Cooling

Reactor effluent is subsequently processed in a series of vessels and heat exchangers before being fed to the fractionation section. Processing includes effluent separation, water wash, cooling, and pressure letdown.

The predominant hazard in this system is the elevated operating pressure and temperature conditions in conjunction with large equipment inventories. After pressure letdown and cooling,




7 .0 - 11

equipment operates at more moderate conditions. Hydrogen sulfide is present at concentrations exceeding the lethal threshold. There are no significant reactive hazards in this section.

The greatest threat to equipment integrity is overtemperature and/or overpressure. Overtemperature may be due to operating upset in the upstream reactors or external fire exposure. Overpressure can result from control system failure (e.g. , pressure letdown control valves failed in the open position) as well as external fire exposure.

To ensure reliable process control and minimize the likelihood of control system failure causing overpressure, redundant transmitters, alarms, and control valves are provided for level control (high pressure letdown) at the High Pressure/High Temperature (HP/HT) Separator.

The major hazards in the gas-liquid separation section are the release of toxic and/or flammable liquids and gases . Streams in this section contain H2S at concentrations that could present exposure hazard for personnel if a significant leak occurred. The installation of an H1S detection and almm system should be considered.

The potential exists for overpressu1ing low pressure piping and equipment due to deadheading or gas blow through from the high pressure separators on loss of level. Protection against overpressuring is done by using a hip system that isolates the high pressure from the low pressure system on low level and emergency relief.

7.1.3.5 High Pressure Amine Absorption

The major hazards in the high pressure amine absorption system are the potential for the release of H2S gas from the feed gas or rich amine and the potential for overpressuring low pressure rich amme p1pmg. Installation of an H2S detection and almm system should be considered.

7.1.3 .6 Compressors

The major hazard involved with compressor operation is the possibility of a hydrogen-rich gas leak due to a major seal failure. To mitigate this hazard, remote isolation valves are provided at the inlet and outlet of each of the compressors. When the isolation valves are closed, the compressors are shut down automatically via an interlock.

Interlocks also protect the compressors from liquid carryover fi:om the first and second stage knock-out dmms, from high compressor discharge temperature and from low suction pressure. Other protective instrumentation will be provided by the compressor vendor per standard machine design practice (e .g. , shutdown on low lube oil pressure, etc). Compressor discharge stages and knock-out drums are protected from overpressure by safety relief valves routed to the flare.

7.1.3.7 Wash Water and Sour Water Degasser

Due to the mild operating conditions and absence of flammable, reactive, or toxic materials, the magnitude of hazards in the Wash Water Surge Drum system is relatively low. Potential back




7.0 - 12

flow from the process on the discharge side of the Wash Water Pumps is addressed via redundant check valves and chopper valve. Drum overpressure protection is provided via a PSV to flare .

The Sour Water Degasser also operates at mild conditions without significant flammable or reactive hazards . However, hydrogen sulfide from sour water feeds to the drum constitutes a potential personnel safety hazard.

7.l.3 .8 Rich Amine Flash Drum

The Rich Amine Flash Drum operates at mild conditions without significant flammable or reactive hazards. However, hydrogen sulfide from the rich amine feeds to the drum constitutes a potential personnel exposure hazard.

7.l.3.9 Catalyst Handling System

With the exception of the Catalyst Transfer Vessels, process vessels in the catalyst transfer system operate at low pressure. During catalyst transfer operations, the Catalyst Trans fer Vessels will be operated intermittently at essentially reactor pressure. Hydrocarbon inventories in individual process vessels are low with the exception of the Catalyst Inventory Holding Bins that will contain a maximum inventory during unit shutdown.

A potential hazard in the operation of the catalyst handling system is the interfacing between the Catalyst Transfer Vessels, which can periodically operate at elevated pressure, and the other process vessels in the system that are designed for low pressure. To protect against possible overpressure of low design pressure equipment, isolation via redundant block valves is provided. For those valves activated by the sequencing system, redundant permissives are provided to minimize the likelihood of incorrect valve positioning.

Reactor fluid can potentially back flow into the Transport Oil Surge Drum upon trip of a Catalyst Transport Oil Pump. To mitigate back flow, redundant check valves are provided in the transport oil path to the Reactors and the Catalyst Transfer Vessels plus interlocks are provided to close the reactor isolation valves .

Overpressure protection of pressure vessels is provided by safety relief valves that discharge to flare. Catalyst inventory bins with low design pressures are protected by relief to the atmosphere.

Heat is removed from the Catalyst Transfer Vessels via cooling oil recirculation through the Circulation Oil Air Cooler. If heat removal should fail due to fan failure or louver closure, high outlet temperature activates an interlock which closes the system back pressure control valve isolating downstream equipment from potential overtemperature and preventing emission of light hydrocarbon vapors to the atmosphere.

During charging of the Catalyst Trans fer Vessels with fresh catalyst, it may be possible for air to enter the process via the Fresh Catalyst Shipping Bins that are vented to atmosphere. To prevent air ently_ the bins are swept with nitrogen. In addition, oxygen is monitored in the Catalyst




7.0 - 13

Transfer Vessel vent system. Nitrogen blanketing is provided for the Catalyst Inventory Holding Bins to protect against possible flammable mixtures in these vessels.

7.1.4 Fire and Explosion Hazards

All hydrocarbons are flammable. Light hydrocarbons--from methane through naphtha--are especially flammable because of their low flash points. Hydrogen is also ve1y flanunable. This means that all leaks must be promptly repaired and spills promptly cleaned up.

Water can expand into steam with explosive force if it comes in contact with a hot source (such as hot oil). At atmosphe1ic pressure, water expands to 1600 times its original volume when it turns to steam. It is essential dming stmtup, to drain all hydrotest and steam-out water before heating any oil over 93°C (200°F), and to drain all low legs, dead ends, and instmment leads. Sample cooler coils should be checked for leaks.

Many fire hazards m·e associated with operating the Residue Hydrocracker. The following special hazards deserve fiuther note.

7.1.4.1 Hydrogen

Hydrogen is a colorless, tasteless, odorless, and highly flanmiable gas mid is the lightest element. Since hydrogen is lighter than air, less danger exists of it collects in pockets in low m·eas. However, the potential danger from fire or explosion is high. Gaseous fuels such as hydrogen can mix with air or oxygen in all proportions. However, the proportions must be within certain limits before those mixtures will bum. The limiting proportions are refeITed to as ' 'flammable limits" or "explosive limits" mid are expressed as the percentage by volume of the fuel in the air-fuel mixture. Fuel-air mixtures outside of the flammable range will not explode. Hydrogen has a very wide range (4-75%) of "flmnmability or explosive limits" in air at atmospheric pressure. In addition, the flanunability range becomes wider at higher pressure, or if oxygen is substituted for air. Thus, explosions can occur over a ve1y wide range of hydrogen concentrations in air. The safest approach to safeguard against possible fires or explosions is to make sure that hydrogen leaks do not develop.

The auto-ignition temperature of a substance is the lowest temperature required to initiate or cause self-sustained combustion in the absence of a spark or flame. The auto-ignition temperature of hydrogen in air is 585°C at atmospheric conditions. However, other factors such as the nature, size, and shape of the igniting surface can affect this temperature.

Unlike most gases, which cool when expanded or bleed oft hydrogen heats up when expanded and great care must be exercised when bleeding down lines or compressors to the atmosphere. In its pure state, hydrogen burns with a bluish white flame (almost invisible) that is extremely hot. Such a hot flame can weaken any support beams or lines on which it may impinge. Any leaks should be put under a steam blanket immediately to prevent the possibility of a fire. Be aware, however, that many leaks can auto-ignite and will be difficult to see.

Because of the small size of hydrogen molecules, a pressure check with air or nitrogen or a hydrostatic test will not always show all leaks that will occur with hydrogen.




7.0 - 14

7.1.4.2 Pressure Hazards

The thick flanges and heavy bolts in the high-pressure system are a good indication of the great forces present in the Residue Hydrocracker. Carefully check bleeds between double blocks before installing pressure gauges or other instruments. Install blinds or screwed plugs on vent and drain valves . Always consider the potential consequences before you open a valve or swing a blind.

7 .1.5 Chemicals Handling and Hazards

Material Safety Data Sheets (MSDSs) outlining health information, safety precautions, and special handling procedures for the catalyst and several of the more hazardous chemicals encountered in the residue hydrocracking process are included at the end of this section. These MSDSs provide information that will be useful in planning and providing for safe working conditions for operating personnel. While these data sheets cover some of the more hazardous chemicals, there are other hazardous chemicals that require special handling for which we have not included bulletins. The following MSDSs for substances that require special handling are included at the end of this section:

• Hydrogen Sulfide (H2S) • Regenerated or Calcined Catalyst • Methyldiethanolamine (MDEA) • Nickel Carbonyl

The following comments are provided to supplement the information presented in the MSDSs and to highlight concerns related to hazards that are more specific to the safe operation of the Residue Hydrocracker.

7.1.5.l Hydrogen Sulfide

H1S is a poisonous (toxic) gas. Lethal H1S poisoning can result from breathing H1S gas, even in very low concentrations . Two forms of poisoning can occur--acute (one exposure) and su bchronic (short-term, mu hi-exposure).

Acute H1S Poisoning - Breathing air or gas containing as little as 0.06-0.10% H2S (600-1000 ppm by volume) for l minute can cause acute poisoning and death. Many sour natural gases or refinery gases contain more than 600 ppm, so care must always be taken to avoid breathing these sour gases . Subchronic H1S Poisoning - Breathing air or gas containing 0.01-0.06% H1S (100-600 ppm by volume) for an hour or more, continuously or intermittently, may cause subchronic H2S po1sonmg.

With the exception of the make-up and recycle hydrogen, all gas streams in the unit will contain high percentages (1-25%) of H1S. In addition, nearly all-liquid product streams will contain substantial quantities of H2S released as vapor if these streams are vented to the atmosphere.




7.0 - 15

Gases that contain high percentages of H2S must NEVER be breathed. One full breath of high concentration H2S gas will cause unconsciousness, and will cause death if the victim falls and remains in the presence of the gas.

7.1.5.2 Prevention of H1S Poisoning

Although H1S has a distinctive and unpleasant odor similar to rotten eggs, the sense of smell is not a positive guide to the presence of H2S. It will frequently paralyze the olfacto1y nerves, destroying the sense of smell to the extent that you do not realize that you are breathing it. Olfactory fatigue and paralysis will occur rapidly at concentrations greater than 150-200 ppm.

This can occur quickly. However, the exact number of breaths or the number of minutes for olfactory fatigue to occur would vary considerably with each individual exposed, and the exact concentration of exposure.

Extreme care must be taken when opening lines and equipment that have contained even low concentrations of H2S. In all cases of doubt, an H2S detector should be used. When drawing samples, venting instrnments, bleeding pumps, etc. , precautions should be taken to avoid breathing the vapors. If any of the applicable exposure limits for hydrogen sulfide are likely to be exceeded, positive supplied-air respiratory protection must be used. (Refer to MSDS at the back of this section for exposure limits.) People should work in pairs. If work should ever have to be done inside equipment containing any H2S, a fresh air mask with continuous air supply must be used. As mentioned above, the atmosphere in which people work must be checked from time to time for small concentrations that would cause subchronic poisoning. REMEMBER -JUST BECAUSE YOUR NOSE SAYS IT'S NOT THERE DOESN'T MEAN THAT IT IS NOT THERE.

Refer to the MSDS at the end of this section for detailed information about H2S.

7.1.5.3 Nickel Carbonyl [NiCCOh}

Nickel carbonyl is a very toxic and volatile substance. Brief exposure to a relatively low concentration can cause severe illness or death. The pennissible exposure limit is 0.00 l ppm or 0.007 mg/m3

.

Nickel carbonyl is formed when dispersed nickel (nickel sulfide as well as elemental nickel) is in the presence of carbon oxides. Temperature has a large effect on nickel carbonyl formation.

Nickel carbonyl formation increases substantially as the system temperature is reduced from normal operating conditions.

During normal operation, it is ve1y unlikely that nickel carbonyl will form because of high operating temperatures. However, during shutdown, the potential for nickel carbonyl formation is greater because the reactor temperatures are lower and nickel is present on the catalyst in a sulfided form. There is also the potential of CO formation during catalyst dumping if air enters




7.0 - 16

the reactors and the oxygen combusts with the carbon on the catalyst. (This combustion reaction requires high temperature.)

In order to prevent the formation of nickel carbonyl, the following measures must be taken:

The reactor temperatures are not allowed to be lower than 204 °C ( 400°F) as long as CO 1s present. During shutdmvn, this requires careful monitoring of make-up hydrogen CO levels.

The CO content of the make-up hydrogen is limited to 10 ppm. As stated above, it is especially important to monitor the make-up hydrogen content during shutdown because this is when the potential for nickel carbonyl formation is the greatest.

During catalyst dumping, air is prevented from entering the reactors by thoroughly purging with hydrogen and nitrogen. A positive nitrogen flow is maintained until catalyst dumping is completed.

Refer to the MSDS at the end of this section for detailed information about nickel carbonyl.




7.0 - 17

7.2 Health

Inadvertent contact with substances processed in the Residue Hydrocracker can have serious health effects. With regard to acute toxicity, personnel exposure to hydrogen sulfide is the greatest concern. The hydrogen sulfide concentration in the workplace will depend upon the effectiveness of fugitive emission controls. Severe leaks may expose personnel to unacceptable concentrations. To address this hazard, the Detailed Design Contractor (DDC) should consider the installation of a hydrogen sulfide detection system and other appropriate safeguards where necessary per pertinent codes and standards.

Contact with high temperature materials as a consequence of leaks or spills can result in severe bums. Appropriate work practices and personal protective equipment are necessary to protect workers from potentially hazardous exposures.

Generally, hydrocarbon process materials have low acute toxicity. Material safety data including physical and chemical properties related to health and safety for catalysts and chemicals are presented at the end of this section. Since normally there are no process hydrocarbon discharges to atmosphere, workplace exposure to process materials usually results from tl1gitive emissions . To control fugitive emissions, the following design approaches have been taken:

• Closed hydrocarbon liquid drain systems are provided to limit discharges to the oily water sewer system to facilitate hydrocarbon recove1y.

• All relief devices in hydrocarbon service are routed to the flare system. Only relief devices in steam and water service may be discharged to atmosphere or sewer.

• All sampling systems are designed to avoid discharge of hydrocarbons to atmosphere.

• All drain and vent valves are normally plugged or blinded.

In addition, the DDC must control fugitive emissions through proper selection of sealing devices such as valve packing, rotating equipment shaft sealing systems, etc. It is the responsibility of Owner to follow a program for leak detection and correction to ensure that regulatory workplace permissible exposure limits are not exceeded.

It is the responsibility of the DDC to address equipment specification for noise abatement. Typical noise sources include rotating equipment, fluid flow throttling devices (i.e. , control valve stations), steam ejectors, etc. Where noise cannot be reduced to within required exposure limits via the intrinsic design of equipment, suitable acoustic barriers and/or personal hearing protection equipment should be provided.




7.0 - 18

7.3 Environment

The Residue Hydrocracker is designed to minimize hmmful environmental impacts. The design includes measures to minimize the amount of waste generated and to control those streams that cannot be eliminated. The detailed design contractor is expected to incorporate CLG's control mechanisms into the mechanical design.

7.3 .1 Emissions

Atmosphere emissions from the Residue Hydrocracker are identified below.

7.3.1.l Furnace Flue Gas

Flue gas from the process fired heaters constitutes the largest volumetric rate emission source from the unit. The actual composition of the flue gas can be determined during detail engineering when heater burner design is finalized.

7.3 .1.2 Vacuum Tower Ejector System Offgas

Non-condensables from the vacuum system are normally incinerated in the Vacuum Tower Feed Heater. Usually a single dedicated burner is used for this purpose. In the event of a severe system leak which permits air ingress, the offgas may become flammable . This condition is usually detected by an elevated gas temperature to the burner. If this occurs, the offgas will be discharged to atmosphere for a short period until the leak source is located and corrected.

7.3 .1.3 Fresh Catalyst Transport Pot (FTCP) Vent

The Fresh Catalyst Transp01t Pot is vented to atmosphere. Normally, there is a small emission of nitrogen as a result of purging the bin. The catalyst is emptied from the vendor supplied bin into the FCTP via gravity displacing diesel overhead. After this step, the head of the FCTP is purged four times to atmosphere with nitrogen to prevent any oxygen from entering the transfer vessels and ultimately the reactors.

7.3 .1.4 Catalyst Invento1y Holding Bins and Spent Cat De-oiling Bins Vent

The Catalyst Inventory Holding Bins and Spent Catalyst De-oiling Bins are nitrogen blanketed and vented to atmosphere. During normal plant operation, these vessels will contain catalyst and oil. Hydrocarbon emissions will occur to a limited extent due to vapor displacement resulting from catalyst/oil filling and vessel breathing.

7.3.1.5 Fugitive Emissions

Fugitive emissions refer to very tiny leaks of volatile organic compounds (VOC) that may occur from such sources as valves, pumps, compressors, and flanges. CLG designs minimize high pressure flanges and valves for safety as well as environmental considerations. Pumps are specified with mechanical seals suitable for design temperature and pressure. Compressors are




7.0 - 19

equipped with seal oil flush systems to prevent leakage to the atmosphere. Sample piping is generally return routed into a process stream or relief header to minimize oil sent to drain or gas to atmosphere.

Equipment should be routinely checked for VOC leaks and properly maintained.

7.3.2 Effluent Summary

Gaseous emissions from the LCMAX Residue Hycirocracking Plant normally consist of combustion flue gases from the fired furnaces and fugitive emissions. No process vents are norn1ally discharged to the atmosphere; vent gases are routed to downstream units for recovery as fuel wherever possible. Where vent stream recovery is not practical, vents are routed to flare to control emissions.

7.3.2 .1 Furnace Combustion Flue Gases

Furnaces are used to heat the reactor and atmospheric and vacuum tower feeds. The ±l.irnaces are fired with fuel gas from the refinery fuel gas system. Combustion gases will be discharged from the furnace stacks. Furnace emissions are limited by the following measures:

• S02 emissions are controlled by the limited amount of sulfur in the fuel gas. • CO emissions are controlled by monitoring the amount of 0 2 in the flue gas. • Low NOx burners could be used to control nitrogen oxide emissions.

7.3.2.2 Process Vent Streams

To control potentially noxious emissions, the vessels listed below are maintained under nitrogen pressure and vented to the flare:

VR Feed Surge Dmm DAO Feed Surge Drum Lean Amine Surge Drum Sour Water Degasser

7.3.2.3 Wastewater

Unit wastewater consists of oily wastewater, oil-free wastewater, sour water, and surface runoff. Chevron designs specify segregated sewer systems for oily and oil-free wastewater sources and surface runoff to ensure proper treatment and cleanup. Oily wastewater is comprised of streams such as water streams from vessels during turnarounds, pump drips, or other leaks . Oily water should be treated offplot to remove suspended solids, dissolved organics, and oil. Steam generator blowdown or once-through cooling water may be considered oil-free wastewater. Sour




7.0 - 20

water is routed offplot for H2S removal prior to being discharged to an offplot sewer. Moreover, heat integration is optimized to limit stripping steam usage and consequently, sour condensate quantity. Discharge outfalls of oily and oil-free rnnoff from the refinery boundary should be continuously monitored for flow, pH, lower explosive limit (LEL), and sulfides .

7.3.2.4 Liquid Wastes

A hydrocarbon layer (oil layer) may accumulate in the H2S absorbers, Rich Amine Flash Drnm, and Sour Water Degasser. The hydrocarbon will be withdrawn and routed to the rich amine.

7.3.3 Effluents

7.3.3.1 Aqueous Efi:luents

Aqueous efiluents consist of various sour water streams produced at a number of points in the process. These streams (excluding sour water from the Vacuum Tower Hotwell) are degassed in the Sour Water Degasser and transferred to battery limit for further processing (e.g., sour water stripping). An estimate of these streams is summarized below.

HP/LT MP/LT Vacuum

Source Tower Separator Separator

Hotwell Flow rate, kg/h 27,892 5,673 59,597 Temperature, °C 56 43 42 H1S, wt% 5.30 2.06 <50ppmw NH3, wt% 2.19 0.82 <15 ppmw Hydrocarbons, ppmw 250 50-100 200

7.3.3.2 Hydrocarbon Drains

Hydrocarbons may be intermittently drained from equipment to facilitate maintenance. These drains are piped to collection systems for appropriate recovery or disposal. The detailed engineering contractor shall provide recovery or disposal systems as required by site regulations.

7.3.3.3 High Pressure I Low Temperature Separator

Process waste water is withdrawn from the Separator. This water consists of water formed during the reaction and wash water injected upstream of the HP/MT Flash Gas Cooler. The water phase containing ammonium bisulfide and hydrocarbons is sent to the Sour Water Degasser first and then to OSBL.


TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE WITH WR ITTEN PERMISSION OF


7.0 - 21

7.3.3.4 Medium Pressure I Low Temperature Separator

The sour water phase, if any, is routed offsite to the OSBL Sour Water Unit via the Sour Water De gasser.

7.3.3.5 Atmospheric Tower, Reflux Drnm and Product Drnm

Stripping steam from the Atmospheric Tower plus water in the Atmospheric Tower overhead collects in the Atmospheric Tower Reflux Drum and the Atmospheric Tower Product Drum. The water phase is typically re-used as part of the injection water in the reaction section.

7.3.3.6 Non-Process Waste Water

Other non-process aqueous waste streams will be produced from operations. Non-process wastewater includes, but is not limited to, maintenance and washdown water, blowdown from steam generators and storm water nm-off. The intermittent and continuous steam drnm blowdown streams may contain high levels of suspended and dissolved solids and will be disposed via the oily water drain.

7.3.4 Solid Wastes

7.3.4.1 Spent Catalyst

Spent catalyst is normally returned to the supplier for reprocessing in sealed containers. An estimated composition summary of spent catalyst can be found below:

Spent Catalyst ICR-622 (wt%)

Base material 44.1 Carbon 13 .2 vs 16.3 NiS 6.3 Oil llJ 20.1 Total 100.0

Quantity of spent catalyst (kg/day) 9060 (I) ~

-LC FINING Diesel




ICR-630 (wt%) 49 .9 15.0 8.6 3.4 23.2 100.0

6580

7.0 - 22

7.3.4.2 Filter Media

Periodically various filter media will require replacement. Disposal of filter media should be in accordance with site environmental regulations.

7.3.5 Spent Catalyst Disposal

Spent catalyst from LC-FINING units is typically processed by catalyst reclaimers who recover the metals. This is done based on a fonnula that includes a processing fee and which gives the LCFININ G licensee a credit for metals content, including molybdenum, vanadium and nickel.

Depending on the market value of the metals at the ti.me of reclamation, the spent catalyst's net value to the LC-FINING licensee can be positive or negative . Most recently, because of the high metals prices, a credit of as much as 40% of the fresh catalyst price has been realized by some of our licensees.

The addresses and contacts for each re-claimer are given below for Sincier's convenience:

• Gulf Chemical & Metallurgical Corp. P. 0. Box 2290 302 Midway Road Freeport, Texas 77541 Contact Person: Jay Jaffee

Phone: 979-233-7882 Fax: 979-233-7171

• Metallurg Vanadium 60790 Southgate Road Cambridge, Ohio 43725 Contact Person: James Carter

Phone: 740-432-6345 (ext. 241) Fax: 740-432-5973

Gulf Chemical's plant is in Freeport, while Metallurg Vanadium' s plant is in Cambridge, Ohio. The feasibility of regenerating the spent catalyst has been evaluated for quite sometime now.

In addition, in Europe there are two reclaimers, Treibacher in Switzerland and Sadaci 111

Belgium.

Steam/air regeneration of catalyst has been thoroughly considered and has been rejected because not enough activity is recovered to make it worthwhile to re-inject this catalyst into the reactor.

In addition, many methods for rejuvenating the catalyst, by actually removing vanadium and nickel contaminants, have been tested. Some of these show promise. However, the chemical leaching of the metals introduces many problems regarding the operation and corrosion of




7.0 - 23

equipment. Such operating and corrosion problems are new to refiners although they are routinely encountered and handled in chemical plants. To date the expense and technical risks associated with such a system has precluded its use.

7.3 .6 Environmental Information to Detailed Design Contractor

Some of the product streams from the Unit are considered volatile organic liquids (VOLs). It is the responsibility of the detailed design contractor to include appropriate emission controls in the design of the facility in accordance with the control method specified by the Owner.

The oily waters from the Unit must be managed to control fogitive emissions of volatile components. It is the responsibility of the detailed engineering contractor to include appropriate equipment and control measures to minimize fugitive emissions from the waste water system.

A closed drain system should be provided to collect hydrocarbons drained from the unit . The closed hydrocarbon drain system will reduce hydrocarbon contamination in the sewer system.

The detailed design contractor shall be responsible for defining all non-process waste water sources and their characteristics , implementing the appropriate waste water segregation system and for providing proper treatment facilities to treat process and non-process waste water prior to final discharge.

7.3.7 Environmental Information to Owner

It is the responsibility of the Owner to define the set of enviro1m1ental perfonnance criteria for detailed engineering design of the facility. These standards include but are not limited to:

• air pollution point source emission control requirements • fugitive emission control strategy • waste water treatment standards

Equipment leaks of VOL's may be controlled through selection of equipment components to minimize emissions and/or through a comprehensive equipment monitoring and repair program. It is the responsibility of the Owner to select the method to control VOL emissions and to communicate these requirements to the detailed design contractor.




Material Safety Data Sheets (MSDS)

Hydrogen Sulfide

Nickel Carbonyl

Methyldiethanolamine (MDEA)

Catalyst (Catalyst Material Safety Data Sheets will be provided separately)



CHEVRON LUMM US GLOBAL

Material Safety Data Sheet

Page 1 of 10

1. CHEMICAL PRODUCT AND COMPANY IDENTIFICATION

HYDROGEN SULFIDE

SYNONYM: H2S

COMPANY IDENTIFICATION

Chev ro n USA Produc ts Company Environmental , Safet y, and Heal th Room 2900 575 Marke t St. San Francisco, CA 94105- 2856

EMERGENCY TELEPHONE NUMBERS

HEALTH (2 4 h r) : (800) 231-0 623 or ( 510 ) 231 - 0623 ( I n ternat i onal) TRANSPORTAT I ON (24 hr) : CHEMTREC (800)4 24 - 93 0 0 or (7 0 3 ) 527 - 3887 Int 'l col l ect calls accepte d

PRODUCT I NFORMATION : ( 8 00) 822 - 5 823 MSDS Reque sts ( 51 0)24 2 - 7 1 3 1 Technical

2. COMPOSITION/INFORMATION ON INGREDIENTS

100.0 % HYDROGEN SULFIDE

CONTAINING

COMPONENTS AMOUNT

HYDROGEN SULFIDE Chemi c al Name : HYDROGEN SULFI DE CAS7 7 830 64

LIMIT/QTY

1 0 ppm 1 5 ppm Table Z- 2 Table Z- 2 100 LBS 5 00 LBS 100 LBS

AGENCY/TYPE

ACGIH TWA ACGIH STEL OSHA PEL OSHA CEILING CERCLA 30 2 . 4 RQ SARA 3 02 TPQ SARA 3 0 4 RQ

I n 1 994, the Nation al I nsti t u te f or Occupational Heal t h and Safety (NIOS H) pu b lished the I mmediate l y Da ngerou s to Li f e a nd Heal t h ( I DLH ) Concentration fo r hyd rogen s ulfi d e as 1 00 ppm .

Revision Nwnber : 11 Revision Date: 11/06/96 MSDS Nwnber : 000301

Chl!'llron

===

HYDROGEN SULFIDE Page 2 of 10

As of t he date of this MS DS , the Occupational Safety and Health Admi n istration (OS HA) is still us i ng the 1988 I DLH o f 300 ppm f or enforcement of workplace safety violation . Check with your local OSHA agency fo r t he current status o f this issue .

COMPOSITION COMMENT: All t he components of this material are o n the To x ic Substances Control Ac t Chemical Substances Inventory .

3 . HAZARDS IDENTIFICATION

************************* EMERGENCY OVERVIEW *************************

Co l o rless gas with rotten egg od or .

- POISON - EXTREMELY FLAMMABLE - MAY BE FATAL IF INHALED - CAUSES EYE IRRITATION - HEAVIER THAN AIR -MAY ACCUMULATE IN LOW PLACES SUCH AS

PITS , TRENCHES, WELL CELLARS AND SUMPS. - ODOR OF ROTTEN EGGS IS NOT A DEPENDABLE INDICATOR OF

PRESENCE OF H2S AT CONCENTRATIONS OVER 100 PPM. - WHEN BURNED, HYDROGEN SULFIDE FORMS SULFUR DIOXIDE

(S02), A POISONOUS, COLORLESS GAS WITH A PUNGENT ODOR.

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POTENTIAL HEALTH EFFECTS EYE: Thi s substance is a moderate eye irritant and could cause prolonged (weeks) impairment o f your vision . The degree o f the injury will depend

o n t he amou n t of materia l that gets i n to the eye a nd t he speed a nd tho r o u ghness of the first aid treatmen t . SKIN: Thi s s ubstance i s n ot e xpected to cause prolonged or significant s k i n irritation . INGESTION: Material is a gas and cannot usually be swallowed . INHALATION : This substance is highly tox ic to internal organs i f inhaled. The degree of i n jury will depend on the airborne concentration a nd duration o f exposure. Hydrogen s ulfide has a strong rotten- egg od or . Howeve r , with continued exposure a nd at high l evels , H2S may dead e n a person ' s sense o f smell . I f t he r otten egg od or is n o longer noticeable , it may not necessarily me an that e xpos ure has stopped . At low levels , hyd roge n su l fide causes irritation o f the eyes , nose a nd throat . Moderate levels can cause headache , d izziness , nausea and vomiting , as well as coughing and difficulty b r eathing. Higher levels can cause shock , convulsions , coma and death . Af t er a serious e xposure , symptoms usually begin immed iately .

Revision Number: 11 Revision Date: 11/06/96 MSDS Number: 000301

HYDROGEN SULFI DE Page 3 of 10

The U. S . National Institute for Occupational Safety and Health (NIOSH) considers air concentrations of hydrogen sulfide gas greater than 100 ppm to be Irrunediately Dangerous to Life and Health (IDLH) .

4. FIRST AID MEASURES

EYE : Fl ush eyes irrunedi ately with fresh water for at least 15 minutes while holding the eyelids open . Remove contact lenses if worn . If irritation persists , see a doctor . SKIN : No first aid procedures are required . As a precaution , wash skin thoroughly with soap and water . See a doctor if any discomfort is experienced . INGESTION: Not expected to be an ingestion problem. See a doctor if any discomfort is exper i enced . INHALATION : DO NOT ATTEMPT TO RESCUE WITHOUT WEARING SELF- CONTAINED BREATHING APPARATUS OR SUPPLIED AIR RESPIRATOR WITH ESCAPE AIR BOTTLE .

If a person is overcome by hydrogen sulfide , you should move the person to fresh air . If breathing has ceased or is labored , you should begin artificial respiration immediately . The affected person should be kept at rest and warm, and placed under a physician ' s care as soon as possible . Because H2S is oxidized quite rapidly in the body , no permanent after - effects should normally occur from acute exposures unless oxgen deprivation of the nervous system is prolonged . NOTE TO PHYSICIANS : Administration of 100% oxygen and supportive care are the preferred treatment for poisoning by hydrogen sulfide gas .

5 . FIRE FIGHTING MEASURES

FLAMMABLE PROPERTIES : FLASH POINT : Gas (NFPA) AUTOIGNITION : 500F (260C) FLAMMAB I LITY LIMITS (%by volume in air) : Lower : 4 . 3 Upper : 45 . 5 EXTINGUISHING MEDIA :

Stop gas flow . Use water for cooling . NFPA RATINGS: Health 3 ; Flammability 4.; Reactivity 0 . FIRE FIGHTING INSTRUCTIONS : This material presents an e x treme fire hazard . Gas forms mixtures with air which can catch fire and burn with explosive violence . Invisible

Revision Number: 11 Revision Date : 11/06/96 MSDS Number : 000301


mixture spreads easily and can be set on fire by many sources such as pilot lights , welding equipment , and electrical motors and switches .

Determine if airborne concentrations are below recommended exposure limits for H2S . If not , wear a NIOSH/MSHA approved air- supplying respirator . COMBUSTION PRODUCTS : Normal combustion produces sulfur dioxide and sulfur trioxide .

6. ACCIDENTAL RELEASE MEASURES

CHEMTREC EMERGENCY NUMBER (24 hr) : (800)424-9300 or (703)527-3887 International Collect Calls Accepted

ACCIDENTAL RELEASE MEASURES : If this material is released into a work area , evacuate the area immediately . Persons entering the contaminated area to correct the problem or to determine whether it is safe to resume normal activities must comply with all instructions in the Exposure Controls/Personal Protection section .

Spills a nd Leak : Any spill or leak , no matter how small , may be a potential hazard . When H2S is detected , prompt notification should be given to appropriate personnel . No one shall enter the area until it has been tested by someone wearing proper respiratory protective equipment . Only workers wearing breathing apparatus shall enter the area until the H2S concentration is below 10 ppm .

Notification : A procedure for notifying appropriate Company and governmental personnel in the event of a release of H2S should be available at each work location . For example : when the concentration of H2S reaches the PEL of 10 ppm , the supervisor or foreman should be notified . Alternate contacts and phone numbers should also be listed . The information transmitted may include the location and size of discharge , wi nd direction and estimated velocity , time leak detected , action taken , and probable cause . Telephone numbers of authorities and agencies should be readily accessible in a contingency plan or be posted .

7. HANDLING AND STORAGE

Toxic quantities of hydrogen sulfide (H2S) may be present . Whenever a potential for exceeding 5 ppm (one - half the PEL) exists , detection and monitoring of hydrogen sulfide should occur . Since the sense of smell cannot be relied upon to detect the presence of H2S , the concentration should be measured by the use of fixed or portable devices .

Soluble in Liquids . High concentrations of H2S may be present in waste water , crude oil, asphalt , bunker fuel , or sludge at the bottom of crude oil storage tanks , as well as in molten sulfur . These liquids may release H2S when agitated or heated .



8. EXPOSURE CONTROLS/PERSONAL PROTECTION

ENGINEERING CONTROLS Use process enclosures , local exhast ventilation , or other engineering controls to control H2S levels below the OSHA Permissible Exposure Limit (PEL ) of 10 ppm .

DETECT I NG AND MON I TORING H2S

Whenever a potential for exceeding 5 ppm (one - half the PEL) exists , detection and mon i toring of hydrogen sulfide should occur . Since the sense of smell cannot be relied upon to detect the presence of the gas , the concentration should be measured by the use of fixed or portable devices . Three broad categories of monitoring instrumentation are : fixed monitors , portable survey- type instruments , and personal monitor/alarm units . To ensure proper operation of monitoring equipment , calibration , testing and maintenance procedures should be followed on a periodic basis . In order to verify the performance of H2S sensing equipment , you should test them with known predetermined concentrations of H2S . Calibration should be done only in a well ventilated area . You should contact the manufacturer for specific calibration procedures . Such work should be performed by trained personnel who are familiar with the equipment and the recognized limitations , if any , of the calibration system in use .

Fixed Monitoring Systems

Continuous fixed monitoring systems are used to constantly measure the concentration of H2S in the atmosphere . Such systems generally consist of control instrumentation , solid state or electrochemical sensors , and alarm devices .

It is suggested that fixed monitors alarm at 10 ppm to alert and warn personnel to evacuate the area or use respiratory protective equipment if they are to remain in the area . Flashing lights are useful in high noise areas where conventional audible alarms are difficult to hear . Care should be taken to choose alarm devices that are easily recognizable and separate from other sirens , horns and lights Alarms should be well distributed to ensure all personnel receive early warning of hazardous concentrations of H2S . In an area with multiple fixed monitors or sensors , you should consider installing warning lights at each sensor location to indicate which monitor has picked up the high concentration .

A fixed monitoring system should be considered for any worksite where continued work activities are likely to create worker exposures to harmful levels of H2S . Examples of such sites are production operations from geological formations known or suspected of containing H2S and certain gas plants , crude gathering systems , tank batteries , refineries , chemical plants and compressor stations . It is desirable to mount the monitor in a control room and place remote sensors at other locations that will maximize detection for personnel both within and outside the plant plot limits . Sensor locations should include the following :



- Areas of potential leak sources - Areas of a plant where personnel normally work - Pump seals - Perimeter of the plant property - Compressor buildings

Consideration should be given to connectiong a fixed monitoring system to emergency power generators so the systems remain operational even during power outages .

Portable Monitoring Devices

Portable devices are electronically or manually operated . The manual devices consist of bellows - type (Draeger) or piston type (Gastec/Bendix, Kitagawa or MSA) pumps that draw air through detector tubes which provide a direct readout of H2S concentrations on the tubes . Sampling probes and hoses are available to allow measurements to be taken remotely from the electronic and detector tube instruments .

The electronic personal H2S montor/alarm units are designed to provide workers with an additional measure of protection by warning o f potentially hazardous levels of H2S within the immediate work area . These are usually set to alarm at the 10 ppm PEL for H2S . Intended for shirtpocket or belt - mounted usage , the compact monitor/alarm units rely upon natural air currents and diffusion principles to detect the presence of H2S . These units typically utilize sensors to continuously monitor H2S level s and activate an alarm (audible or visble ) when measured H2S levels exceed a predetermined setpoint . Most monitor/alarm units are also available with earphones for use in high - noise area . Such personal H2S monitor/alarm units should be considered for use during work activities in suspect areas not provided with fixed continuous monitoring systems . The use of H2S indicating badges or tapes i s not recommended .

Montinoring Procedures

You shou l d monitor areas suspected of containing harmful levels of H2S before permitting personnel to work in the area or atmosphere . Work can be performed for an eight hour peridod in a concentration up to 10 ppm , as long as continual checks are made . Whenever the concentration o f H2S exceeds 10 ppm , the area should be vacated and appropriate personnel informed . The area shall only be reentered by personnel wearing positive- pressure self - contained or supplied air respiratory protective equipment or when the level of H2S has been measured below 10 ppm .

In area suspected o f containing concentrations o f H2S in excess o f 10 ppm , such as areas where a leak has occurred , the worker performing the test must wear a se l f - contained breathing apparatus (SCBA) or supplied air respirator with an escape air bottle and if not within voice or visual range of other workers , be equipped with a communication device . If exposures are likely to exceed the IDLH , a second person is neede d as a standby with a SCBA in a safe area . (Note : if the suspect area i s a confined space, the worker performing the test shall have a life line attached and a standby shall be provided .

PERSONAL PROTECTIVE EQUIPMENT EYE/FACE PROTECTION : Do not get this material in your eyes . Eye contact can be avoided by


HYDROGEN SULFI DE

wearing chemical goggles . SKIN PROTECTION : No special skin protection is necessary . RESPIRATORY PROTECTION : RESP I RATORY PROTECTIVE EQUIPMENT

Page 7 of 10

Respiratory protective equipment should be available to all employees who cou l d be exposed above the permitted exposure limits for H2S .

Only positive- pressure breathing air respiratory protective equipment is acceptable . Air purifying devices are not permitted .

Fixed or portable manifolds for supplied air may serve one or more workers and shou ld be l ocated to minimize the length of breathing air hose required. Supplied air respirators or SCBAs shall be of the positive pressure type and have an alarm system for low air supply .

All breathing apparatus should be located at clearly identified stations within the work area . The location of respirators should be planned to assure at least one extra available breathing apparatus . Posted maps indicating t he location of SCBAs can be a useful emergency aid in a facility .

9. PHYSICAL AND CHEMICAL PROPERTIES

PHYSICAL DESCRIPTION : Colorless gas

pH : VAPOR PRESSURE : VAPOR DENSITY

(AIR=l) : BOILING POINT : MELTING POINT :

with rotten egg odor. NOA 18 . 5 ATM @ 20C

1.18 - 76F - 122F

(- 60C) (- 86C)

SOLUBILITY : SPECIFIC GRAVITY :

Soluble in water , alcohol , and petroleum fractions . 1.54 liquified

EVAPORAT I ON RATE : PERCENT VOLAT I LE

(VOL ): MOLECULAR WEIGHT :

NA

NA 34

10. STABILITY AND REACTIVITY

HAZARDOUS DECOMPOSITION PRODUCTS : NOA CHEMICAL STABILITY : Stable . CONDITIONS TO AVOID : Highly Corrosive . In addition to general loss of metal and strength, H2S corrosion may produce stresses which cause deformation and cracks . Materials resistant to these effects should be selected for use in H2S environment s . In the presence of moisture , H2S attacks many metals f orming



sulfides that may produce exothermic reactions that can generate high temperatures with air when dried. INCOMPATIBILITY WITH OTHER MATERIALS: May react with strong oxidizing agents, such as chlorates, nitrates, peroxides, etc. HAZARDOUS POLYMERIZATION: Polymerization will not occur.

11. TOXICOLOGICAL INFORMATION

EYE EFFECTS: No product toxicology data available. SKIN EFFECTS: No product toxicology data available. ACUTE ORAL EFFECTS: No product toxicology data available. ACUTE INHALATION EFFECTS: No product toxicology data available.

12. ECOLOGICAL INFORMATION

ECOTOXICITY: The 96-hour LCSO for bluegill sunfish (Lepornis rnacrochirus) is less than 0.05 rng/l. ENVIRONMENTAL FATE: No data available.

13. DISPOSAL CONSIDERATIONS

Eliminate all sources of ignition in vicinity of spill or release. Allow to evaporate with adequate ventilation.

14. TRANSPORT INFORMATION

The description shown may not apply to all shipping situations. Consult 49CFR, or appropriate Dangerous Goods Regulations, for additional description requirements (e.g., technical name) and mode-specific or quantity-specific shipping requirements.

DOT SHIPPING NAME: PRODUCT/MATERIAL NOT CURRENTLY SHIPPED DOT HAZARD CLASS: NONE DOT IDENTIFICATION NUMBER: NONE DOT PACKING GROUP: NONE


HYDROGEN SULFIDE

15 . REGULATORY INFORMATION

SARA 311 CATEGORIES : 1. 2 . 3 . 4 . 5 .

REGULATORY LISTS SEARCHED :

Page

Immediate (Acu te) Health Effects : Delayed (Chronic ) Health Effects : Fi re Hazard : Sudden Release of Press u re Hazard: Reactivity Hazard :

YES NO YES NO NO

9 of 10

Ol=SARA 3 1 3 02=MASS RTK 03=NTP Carcinogen 04=CA Prop 65 - Carcin 05=CA Pr op 65 - Repro Ta x 06=IARC Group 1 07=IARC Group 2A OB=IARC Group 2B 09=SARA 302/304

ll=NJ RTK 12=CERCLA 302 . 4 13=MN RTK 14=ACGIH TWA 15=ACGIH STEL 16=ACGIH Cale TLV 17=0SHA PEL lB=DOT Marine Pollutant 19=Chevron TWA

22=TSCA Sect 5 (a ) (2 ) 23=TSCA Sect 6 24=TSCA Sect 12 (b) 25=TSCA Sect B(a ) 26=TSCA Sect B(d) 27=TSCA Sect 4( a ) 28=Canad ian WHMIS 29=0SHA CEILING 30=Chevron STEL

l O=PA RTK 20=EPA Carcinogen

The following components o f this material are found on the regulatory li s t s i ndicated .

HYDROGEN SULFIDE i s found on li sts : Ol , 02 , 09 ,1 0 , 11 , 12 , 13 , 14 ,1 5 , 17 , 28 , 29 ,

16 . OTHER INFORMATION

NFPA RATINGS: Health 3; Flaromability 4 ; Reactivity O; (0 - Least , 1-Slight , 2 - Moderate , 3 - High , 4- Ext reme , PPE :- Personal Protection Equipment Index recommendation , *- Chronic Effect Indicator) . These values are obtained using the guidelines or publi shed eva luations prepared by the National Fire Protection Assoc iation (NF PA) or the National Pain t and Coating Association (for HMIS ratings) .

REVISION STATEMENT: Changes have been made throughout this Material Safety Data Sheet . Please read t he entire d ocument .

ABBREVIATIONS THAT MAY HAVE BEEN USED IN THIS DOCUMENT: TLV - Threshold Limit Value STEL - Short - t e rm Exposure Limit RQ - Repor table Quant ity C - Ce i l ing Li mit Al - 5 - Appendix A Categories NDA - No Data Available

TWA - Time Weighted Average TPQ - Threshold Planning Quan tity PEL - Permissible Exposure Limit CAS - Chemical Abstract Service Number () - Change Has Been Proposed

NA - Not Applicable

Prepared according to the OSHA Hazard Communication Standard

Revision Number : 11 Revision Date: 11/06/96 MSDS Number: 000301


(29 CFR 1910.1200) and the ANSI MSDS Standard (Z400.1) by the Toxicology and Health Risk Assessment Unit, CRTC, P.O. Box 4054, Richmond, CA 94804

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The above information is based on the data of which we are aware and is believed to be correct as of the date hereof. Since this information may be applied under conditions beyond our control and with which we may be unfamiliar and since data made available subsequent to the date hereof may suggest modification of the information, we do not assume any responsibility for the results of its use. This information is furnished upon condition that the person receiving it shall make his own determination of the suitability of the material for his particular purpose.

********************************************************************** THIS IS THE LAST PAGE OF THIS MSDS

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Material Safety Data Sheet 24-Hour Emergency Telephone Numbers HEAL TH : Chevron Emergency Information Center (800) 231-0623 or (510) 231-0623 TRANSPORTATION: CHEMTREC (800) 424-9300 or (703) 527-3887 Emergency Information Centers are located in the U.S.A. International collect calls accepted .

I SECTION 1 PRODUCT AND COMPANY IDENTIFICATION

Nickel Carbonyl

Product Information Company Identification Chevron Products Company Marketing, MSDS Coordinator 600 1 Bollinger Canyon Road San Ramon,CA 94583

MSDS Requests: (800) 689-3998

I SECTION 2 COMPOSITION/ INFORMATION ON INGREDIENTS

COMPONENTS CASNUMBER AMOUNT Nickel Carbonyl 13463-39-3 100 %weight

I SECTION 3 HAZARDS IDENTIFICATION

************************************************************************************************************************ EMERGENCYOVER~EW

Colorless to brownish volatile liquid with sooty or musty odor.

- EXTREMELY FLAMMABLE LIQUID AND VAPOR. VAPOR MAY CAUSE FLASH FIRE - MAY BE FATAL IF SWALLOWED - MAY BE FATAL IF INHALED - CAUSES RESPIRATORY TRACT IRRITATION IF INHALED - CAUSES SEVERE EYE IRRITATION - MAY CAUSE AN ALLERGIC SKIN REACTION - CAUSES SKIN IRRITATION - CANCER HAZARD - CAN CAUSE CANCER - POSSIBLE BIRTH DEFECT HAZARD - MAY CAUSE BIRTH DEFECTS BASED ON ANIMAL DATA

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IMMEDIATE HEAL TH EFFECTS Eye: Contact with the eyes causes severe irritation. Symptoms may include pain , tearing , reddening , swelling and impaired vision . Skin: Not expected to be harmful to internal organs if absorbed through the skin . Contact with the skin causes irritation . Contact with the skin may cause an allergic skin reaction. Symptoms may include pain , itching, discoloration, swelling , and blistering . Ingestion: Highly toxic ; may be fatal if swallowed. May be irritating to mouth , throat, and stomach.

Revision Number: 6 Revision Date: 04/04/2001

1 of 6 Nickel Carbonyl MSDS : 739

Symptoms may include nausea, vomiting , and diarrhea. Inhalation: Highly toxic; may be fatal if inhaled . The vapor or fumes from this material may cause severe respiratory irritation . Symptoms of respiratory irritation may include coughing and difficulty breathing . See Section 11.

DELAYED OR OTHER HEAL TH EFFECTS: Reproduction and Birth Defects: Breathing this material may cause birth defects based on animal data. Cancer: Prolonged or repeated exposure to this material can cause cancer. Contains nickel compounds , which have been classified as a Group 1carcinogens (carcinogenic to humans) by the International Agency for Research on Cancer (IARC) and Reasonably Anticipated to be Carcinogenic in humans by the USA National Toxicology Program (NTP).

See Section 11 for additional information. Risk depends on duration and level of exposure.

I SECTION 4 FIRST AID MEASURES

Eye: Flush eyes with water immediately while holding the eyelids open . Remove contact lenses, if worn , after initial flushing , and continue flushing for at least 15 minutes. Get immediate medical attention . Skin: Wash skin with water immediately and remove contaminated clothing and shoes . Get medical attention if any symptoms develop. To remove the material from skin, use soap and water. Discard contaminated clothing and shoes or thoroughly clean before reuse. Ingestion: If swallowed, do not induce vomiting . Give the person a glass of water or milk to drink and get immediate medical attention . Never give anything by mouth to an unconscious person . Inhalation: For emergencies , wear a NIOSH approved air-supplying respirator. Move the exposed person to fresh air. If not breathing , give artificial respiration . If breathing is difficult, give oxygen. Get immediate medical attention .

I SECTION 5 FIRE FIGHTING MEASURES

See Section 7 for proper handling and storage.

NFPA RATINGS: Health: 4

FLAMMABLE PROPERTIES: Flashpoint: -4 °F Autoignition: 140°F (60°C)

Flammability: 3 Reactivity: 3

Flammability (Explosive) Limits (%by volume in air): Lower: 2 Upper: NOA

EXTINGUISHING MEDIA: Use water fog , foam , dry chemical or carbon dioxide (C02) to extinguish flames .

PROTECTION OF FIRE FIGHTERS: Fire Fighting Instructions: For fires involving this material , do not enter any enclosed or confined fire space without proper protective equipment, including self-contained breathing apparatus. Combustion Products: Highly dependent on combustion conditions . A complex mixture of airborne solids, liquids, and gases including carbon monoxide, carbon dioxide, and unidentified organic compounds will be evolved when this material undergoes combustion . Combustion may form oxides of: Nickel .

I SECTION 6 ACCIDENTAL RELEASE MEASURES

Protective Measures: Eliminate all sources of ignition in the vicinity of the spill or released vapor. If this material is released into the work area , evacuate the area immediately. Monitor area with combustible

Revision Number: 6 Revision Date : 04/04/2001


gas indicator. Spill Management: Stop the source of the release if you can do it without risk . Contain release to prevent further contamination of soil , surface water or groundwater. Clean up spill as soon as possible. observing precautions in Exposure Controls/Personal Protection . Use appropriate techniques such as applying non-combustible absorbent materials or pumping. All equipment used when handling the product must be grounded. A vapor suppressing foam may be used to reduce vapors. Use clean nonsparking tools to collect absorbed material. Where feasible and appropriate, remove contaminated soil. Place contaminated materials in disposable containers and dispose of in a manner consistent with applicable regulations. Reporting : Report spills to local authorities and/or the U.S. Coast Guard's National Response Center at (800) 424-8802 as appropriate or required.

I SECTION 7 HANDLING AND STORAGE

Precautionary Measures: This product presents an extreme fire hazard . Liquid very quickly evaporates , even at low temperatures, and forms vapor (fumes) which can catch fire and burn with explosive violence. Invisible vapor spreads easily and can be set on fire by many sources such as pilot lights, welding equipment, and electrical motors and switches. Do not get in eyes, on skin , or on clothing . Do not get in eyes. Do not taste or swallow. Wash thoroughly after handling. Do not breathe vapor or fumes. Unusual Handling Hazards: Nickel carbonyl may be formed in vessels where carbon monoxide contacts finely-divided nickel in the reduced state. While these conditions are not likely to occur with spent refinery catalysts; the toxicity of nickel carbonyl is of such concern that proper precautions are warranted. Therefore, vessels containing spent catalysts should be purged with a CO-free gas until the absence of nickel carbonyl is assured. Static Hazard: Electrostatic charge may accumulate and create a hazardous condition when handling this material. To minimize this hazard, bonding and grounding may be necessary but may not, by themselves, be sufficient. Review all operations which have the potential of generating an accumulation of electrostatic charge and/or a flammable atmosphere (including tank and container filling , splash filling , tank cleaning , sampling , gauging, switch loading, filtering , mixing, agitation , and vacuum truck operations) and use appropriate mitigating procedures . For more information, refer to OSHA Standard 29 CFR 1910.106, 'Flammable and Combustible Liquids', National Fire Protection Association (NFPA 77 , 'Recommended Practice on Static Electricity', and/or the American Petroleum Institute (API ) Recommended Practice 2003, 'Protection Against Ignitions Arising Out of Static, Lightning, and Stray Currents' . General Storage Information: DO NOT USE OR STORE near heat, sparks or open flames . USE AND STORE ONLY IN WELL VENTILATED AREA. Keep container closed when not in use.

I SECTION 8 EXPOSURE CONTROLS/PERSONAL PROTECTION

GENERAL CONSIDERATIONS: Consider the potential hazards of this material (see Section 3), applicable exposure limits, job activities, and other substances in the work place when designing engineering controls and selecting personal protective equipment. If engineering controls or work practices are not adequate to prevent exposure to harmful levels of this material, the personal protective equipment listed below is recommended . The user should read and understand all instructions and limitations supplied with the equipment since protection is usually provided for a limited time or under certain circumstances.

ENGINEERING CONTROLS: Use process enclosures, local exhaust ventilation , or other engineering controls to control airborne levels below the recommended exposure limits.

PERSONAL PROTECTIVE EQUIPMENT Eye/Face Protection: Wear eye protection such as safety glasses, chemical goggles, or faceshields if engineering controls or work practices are not adequate to prevent eye contact. Skin Protection: Wear protective clothing to prevent skin contact. Selection of protective clothing may



include gloves , apron , boots, and complete facial protection depending on operations conducted . Suggested materials for protective gloves include: Chlorinated Polyethylene (or Chlorosulfonated Polyeth ylene), or Nitrile Rubber, or Polyvinyl Chloride (PVC or Vinyl), or Viton Respiratory Protection : Determine if airborne concentrations are below the recommended exposure limits. If not, wear a NIOSH approved respirator that provides adequate protection from measured concentrations of this material , such as : Full-Face Supplied-Air Respirator Use a positive pressure, air-supplying respirator if there is potential for uncontrolled release , exposure levels are not known, or other circumstances where air-purifying respirators may not provide adequate protection.

Occupational Exposure Limits:

Component Limit TWA STEL Ceilinq Nickel Carbonyl OSHA_PEL 0.001 ppm

Nickel Carbonyl ACGIH_TLV 0.05 ppm

I SECTION 9 PHYSICAL AND CHEMICAL PROPERTIES

Appearance and Odor: Colorless to brownish volatile liquid with sooty or musty odor. pH: NA Vapor Pressure: 400 mmHg @ 79 °F Vapor Density (Air= 1): 5.89 Boiling Point: 109 °F Solubility: Soluble in hydrocarbon solvents ; insoluble in water. Melting Point: -13 °F Specific Gravity: 1.32 @ 17 °C (H20 = 1)

I SECTION 10 STABILITY AND REACTIVITY

Notation

Chemical Stability: Material is dangerously unstable. See 'Conditions to Avoid ' and/or 'Incompatibility With Other Materials' in this section . Conditions to Avoid: May decompose and explode when heated above 140 °F. Incompatibility With Other Materials : May form explosive peroxides upon exposure to air . May react with strong oxidizing agents, such as chlorates, nitrates, peroxides, etc. Hazardous Decomposition Products: Carbon Monoxide (Elevated temperatures) Hazardous Polymerization: Hazardous pol ymerization will not occur.

I SECTION 11 TOXICOLOGICAL INFORMATION

IMMEDIATE HEAL TH EFFECTS Eye Irritation: Based on information from published scientific literature. Skin Irritation: Based on information from published scientific literature. Skin Sensitization: Based on information from published scientific literature. Acute Dermal Toxicity: The 4 hour(s) LD50 in the rat is not available. Acute Oral Toxicity: The LD50 in the rat is not available. Acute Inhalation Toxicity: The 30 minute(s) LC50 in the rat is 35 ppm .

ADDITIONAL TOXICOLOGY INFORMATION: This material contains Nickel Carbonyl. Vapor concentrations above the exposure standard may cause initial headache, giddiness, weakness of limbs, cold and clammy skin, increased perspiration , nausea, vomiting, tightness of chest, coughing and breathing difficulties. Removal to fresh air usually brings relief

Revision Number: 6 Revision Date: 04/04/2001


from symptoms. However, within 12 to 36 hours later, sharp chest pains accompanied by rapid breathing and rising temperature may occur. In addition , dizziness, nausea , vomiting , metallic taste, insomnia and anxiety may be present. In severe cases, rapid pulse, delirium , convulsions and other signs and symptoms of central nervous system disturbances may appear. Death may occur from delayed chemical pneumonitis and pulmonary edema.

I SECTION 12 ECOLOGICAL INFORMATION

ECOTOXICITY The toxicity of this material to aquatic organisms has not been evaluated. Consequently, this material should be kept out of sewage and drainage systems and all bodies of water.

ENVIRONMENTAL FATE This material is expected to be readily biodegradable .

I SECTION 13 DISPOSAL CONSIDERATIONS

Use material for its intended purpose or recycle if possible. This material , if it must be discarded, may meet the criteria of a hazardous waste as defined by US EPA under RCRA (40 CFR 261 ) or other State and local regulations. Measurement of certain physical properties and analysis for regulated components may be necessary to make a correct determination . If this material is classified as a hazardous waste, federal law requires disposal at a licensed hazardous waste disposal facility.

I SECTION 14 TRANSPORT INFORMATION

The description shown may not apply to all shipping situations . Consult 49CFR, or appropriate Dangerous Goods Regulations, for additional description requirements (e.g. , technical name) and modespecific or quantity-specific shipping requirements.

I SECTION 15 REGULATORY INFORMATION

SARA 311/312 CATEGORIES: 1. Immediate (Acute) Health Effects: 2. Delayed (Chronic) Health Effects: 3. Fire Hazard: 4. Sudden Release of Pressure Hazard: 5. Reactivity Hazard:

YES YES YES NO YES

REGULATORY LISTS SEARCHED: 4A=IARC Group 1 12=TSCA Sect ion 8(a) PAIR 21=TSCA Section 5(a)

4B=IARC Group 2A 13=TSCA Section 8(d) 25=CAA Section 112 HAPs

4C=IARC Group 28 15=SARA Section 313 26=CWA Section 31 1

05=NTP Carcinogen 16=CA Proposit ion 65 28=CWA Section 307

06=0SHA Carcinogen 17=MA RTK 30=RCRA Waste P-List

09=TSCA 12(b) 18=NJ RTK 31 =RCRA Waste U-List

10=TSCA Section 4 19=DOT Marine Pollutant 32=RCRA Appendix VIII

11 =TSCA Section 8(a) CAIR 20=PA RTK

The following components of this material are found on the regulatory lists indicated. Nickel Carbonyl 4A, 05 , 16, 17, 18, 19, 20, 25, 30, 32

CERCLA REPORTABLE QUANTITIES(RQ)/SARA 302 THRESHOLD PLANNING QUANTITIES(TPQ):



Component Component RQ Component TPQ Product RQ

Nickel Carbonyl None 1 lbs 1 lbs

Nickel Carbonyl 10 lbs None 10 lbs

CHEMICAL INVENTORIES: UNITED STATES: All of the components of this material are on the Toxic Substances Control Act (TSCA) Chemical Inventory. WHMIS CLASSIFICATION: Class B, Division 2: Flammable Liquids Class D, Division 1, Subdivision A: Very Toxic Material -Acute Lethality Class D, Division 2, Subdivision A: Very Toxic Material -Carcinogenicity Teratogenicity and Embryotoxicity Class D, Division 2, Subdivision B: Toxic Material -Skin Sensitization Skin or Eye Irritation

I SECTION 16 OTHER INFORMATION

NFPA RATINGS: Health: 4 Flammability: 3 Reactivity: 3

(0-Least, 1-Slight, 2-Moderate, 3-High , 4-Extreme, PPE :- Personal Protection Equipment Index recommendation , *-Chronic Effect Indicator). These values are obtained using the guidelines or published evaluations prepared by the National Fire Protection Association (NFPA) or the National Paint and Coating Association (for HMIS ratings).

REVISION STATEMENT: This document has been reactivated , reformated , and extensively revised . Read all sections.

ABBREVIATIONS THAT MAY HAVE BEEN USED IN THIS DOCUMENT: TLV Threshold Limit Value TVl/A Time Weighted Average STEL Short-term Exposure Limit PEL Permissible Exposure Limit

CAS Chemical Abstract Service Number NOA No Data Avai lable NA Not Applicable <= Less Than or Equal To >= Greater Than or Equal To

Prepared according to the OSHA Hazard Communication Standard (29 CFR 1910.1200) and the ANSI MSDS Standard Z400.1 .

The above information is based on the data of which we are aware and is believed to be correct as of the date hereof. Since this information may be applied under conditions beyond our control and with which we may be unfamiliar and since data made available subsequent to the date hereof may suggest modifications of the information, we do not assume any responsibility for the results of its use. This information is furnished upon condition that the person receiving it shall make his own determination of the suitability of the material for his particular purpose.



r4~ 4TDFIN4 METHYLDIETHANOLAMINE Material Safety Data Sheet - A TOFINA Chemicals, Inc.

1 PRODUCT AND COMPANY IDENTIFICATION

Organic Chemicals EMERGENCY PHONE NUMBERS:

ATOFINA Chemicals, Inc. 2000 Market Street

Chemtrec: (800) 424-9300 (24hrs) or (703) 527-3887 Medical: Rocky Mountain Poison Control Center

Philadelphia, PA 19103 (303) 623-5716 (24Hrs)

Information Telephone Numbers Phone Number

Customer Service

Product Name Product Synonym(s)

Chemical Family

Chemical Formula Chemical Name EPA Reg Num Product Use

1-800-628-4453

METHYLDIETHANOLAMINE MDEA

Alkyl Alkanolamine

CH3N(C2H40H)2 Ethanol, 2,2'-(Methylimino) bis-

2 COMPOSITION/ INFORMATION ON INGREDIENTS

Ingredient Name

Methyldiethanolamine

Water

CAS RegistryNumber

105-59-9

7732-18-5

Available Hrs

8:30 to 5:30 EST

Typical Wt % OSHA ~~~~~~~~

99% y

0.3% N

The substance(s) marked with a "Y" in the OSHA column, are identified as hazardous chemicals according to the criteria of the OSHA Hazard Communication Standard (29 CFR 1910. 1200)

This material is classified as hazardous under Federal OSHA regulation.

The components of this product are all on the TSCA Inventory list

3 HAZARDS IDENTIFICATION

Emergency Overview Pale straw liquid with amine odor

WARNING! CAUSES EYE IRRITATION.

Potential Health Effects

Inhalation and skin contact are expected to be the primary routes of occupational exposure to this material. Based on single exposure animal tests, it is considered to be slightly toxic if swallowed, practically non-toxic if absorbed through skin, severely irritating to eyes and practically non-irritating to skin.

Product Code: 002146 Revision: 6 lssued:08 APR 2003 Page 1 of 6


4 FIRST AID MEASURES

IF IN EYES, immediately flush with plenty of water for at least 15 minutes. Get medical attention.

IF ON SKIN, immediately flush with plenty of water. Remove contaminated clothing and shoes. Get medical attention. Wash clothing before reuse. Thoroughly clean shoes before reuse.

IF SWALLOWED, do NOT induce vomiting. Give water to drink. Get medical attention immediately. NEVER GIVE ANYTHING BY MOUTH TO AN UNCONSCIOUS PERSON.

IF INHALED, remove to fresh air. If not breathing, give artificial respiration. If breathing is difficult, give oxygen. Get medical attention.

5 FIRE FIGHTING MEASURES

Fire and Explosive Properties Auto-Ignition Temperature Flash Point Flammable Limits- Upper

Lower

Extinguishing Media

770 F (410 C) 240 F 8.8 1.4

Use water spray, carbon dioxide, foam or dry chemical.

Fire Fighting Instructions

Flash Point Method PMCC

Fire fighters and others who may be exposed to products of combustion should wear full fire fighting turn out gear (full Bunker Gear) and self-contained breathing apparatus (pressure demand NIOSH approved or equivalent). Fire fighting equipment should be thoroughly decontaminated after use.

Fire and Explosion Hazards

When burned, the following hazardous products of combustion can occur: Oxides of carbon and nitrogen

6 ACCIDENTAL RELEASE MEASURES

In Case of Spill or Leak

Small spills may be flushed away with large volume of water. Consult a regulatory specialist to determine appropriate state or local reporting requirements, for assistance in waste characterization and/or hazardous waste disposal and other requirements listed in pertinent environmental permits.

7 HANDLING AND STORAGE

Handling

Avoid contact with eyes. Wash thoroughly after handling.

Emptied container retains vapor and product residue. Observe all labeled safeguards until container is cleaned, reconditioned or destroyed.

Storage

This material is not hazardous under normal storage conditions; however, material should be stored in closed containers, in a secure area to prevent container damage and subsequent spillage.



7 HANDLING AND STORAGE

8 EXPOSURE CONTROLS I PERSONAL PROTECTION

Engineering Controls

Investigate engineering techniques to reduce exposures. Provide ventilation if necessary to minimize exposure. Dilution ventilation is acceptable, but local mechanical exhaust ventilation preferred, if practical, at sources of air contamination such as open process equipment

Eye I Face Protection

Where there is potential for eye contact, wear chemical goggles and have eye flushing equipment immediately available.

Skin Protection

Minimize skin contamination by following good industrial hygiene practice. Wearing rubber gloves is recommended. Wash hands and contaminated skin thoroughly after handling.

Respiratory Protection

Where airborne exposure is likely, use NIOSH approved respiratory protection equipment appropriate to the material and/or its components. If exposures cannot be kept at a minimum with engineering controls, consult respirator manufacturer to determine appropriate type equipment for a given application. Observe respirator use limitations specified by NIOSH or the manufacturer. For emergency and other conditions where there may be a potential for significant exposure, use an approved full face positive-pressure, self-contained breathing apparatus or positive-pressure airline with auxiliary self-contained air supply. Respiratory protection programs must comply with 29 CFR § 1910.134.

Airborne Exposure Guidelines for Ingredients

The components of this product have no established Airborne Exposure Guidelines

-Only those components with exposure limits are printed in this section. -Skin contact limits designated with a "Y" above have skin contact effect. Air sampling alone is insufficient to accurately quantitate exposure. Measures to prevent significant cutaneous absorption may be required. -ACGIH Sensitizer designator with a value of "Y" above means that exposure to this material may cause allergic reactions. -WEEL-AIHA Sensitizer designator with a value of "Y" above means that exposure to this material may cause allergic skin reactions.

9 PHYSICAL AND CHEMICAL PROPERTIES

Appearance/Odor

pH Specific Gravity Vapor Pressure Vapor Density Melting Point Freezing Point Boiling Point Solubility In Water Evaporation Rate Percent Volatile Molecular Weight

Product Code: 002146

Pale straw liquid with amine odor

NE 1.04 @20 c <0.01 mmHg @ 20 C 4 NA -21 C (-5.8 F) 240-255 C (464-491 F ) Complete NE 100 119.2

Revision: 6 lssued:08 APR 2003 Page 3 of 6


10 STABILITY AND REACTIVITY

Stability

This material is chemically stable under normal and anticipated storage and handling conditions.

Incompatibility Avoid contact with strong acids, strong alkalis, and strong oxidizers.

Hazardous Decomposition Products Thermal decomposition giving off toxic and corrosive products: ammonia, carbon dioxide, nitrogen dioxides.

11 TOXICOLOGICAL INFORMATION

Toxicological Information

Data on this material and/or its components are summarized below.

Single exposure (acute) studies indicate: Oral - Slightly Toxic to Rats (LD50 4,780 mg/kg) Dermal - Practically Non-toxic to Rabbits (LD50 6,300 mg/kg) Inhalation - No deaths in rats following exposure to saturated vapor for 8-hours Eye Irritation - Severely Irritating to Rabbits (59/110) Skin Irritation - Practically Non-irritating to Rabbits (4-hr exposure, 0.2/8.0) No skin allergy was observed in guinea pigs following repeated exposure. Severe irritation, but no systemic

effects, were observed following repeated application to the skin of rats. No birth defects were observed in the offspring of rats following application to the skin during pregnancy, even a doses which produced adverse effects on the mothers. No genetic changes were observed in tests using bacteria or animals.

12 ECOLOGICAL INFORMATION

Ecotoxicological Information

No data are available.

Chemical Fate Information

No data are available.

13 DISPOSAL CONSIDERATIONS

Waste Disposal

Incineration is the recommended method for disposal observing all local, state and federal regulations. Note: Chemical additions to, processing of, or otherwise altering this material may make this waste management information incomplete, inaccurate, or otherwise inappropriate. Furthermore, state and local waste disposal requirements may be more restrictive or otherwise different from federal laws and regulations.



14 TRANSPORT INFORMATION

DOT Name Not Regulated by DOT DOT Technical Name DOT Hazard Class UN Number DOT Packing Group RQ

PG

15 REGULATORY INFORMATION

Hazard Categories Under Criteria of SARA Title Ill Rules (40 CFR Part 370)

Immediate (Acute) Health Y Fire N Delayed (Chronic) Health N Reactive N

Sudden Release of Pressure N

The components of this product are all on the TSCA Inventory list

Ingredient Related Regulatory Information:

SARA Reportable Quantities

Water Methyldiethanolamine

Chemical Weapons Convention Methyldiethanolamine

16 OTHER INFORMATION

Revision Information

Revision Date 08 APR 2003 Supercedes Revision Dated 21-FEB-2003

Revision Summary Reviewed and revised.

Key

CERCLA RQ

NE

NE

Revision Number 6

NE= Not Established NA= Not Applicable (R) = Registered Trademark

Product Code: 002146 Revision: 6 Issued: 08 APR 2003

SARA TPQ

Page 5 of 6


ATOFINA Chemicals, Inc. believes that the information and recommendations contained herein (including data and statements) are accurate as of the date hereof. NO WARRANTY OF FITNESS FOR ANY PARTICULAR PURPOSE, WARRANTY OF MERCHANTABILITY, OR ANY OTHER WARRANTY, EXPRESSED OR IMPLIED, IS MADE CONCERNING THE INFORMATION PROVIDED HEREIN. The information provided herein relates only to the specific product designated and may not be valid where such product is used in combination with any other materials or in any process. Further, since the conditions and methods of use are beyond the control of ATOFINA Chemicals, ATOFINA Chemicals expressly disclaims any and all liability as to any results obtained or arising from any use of the product or reliance on such information.


8.0 - Utility Summary

This section contains the estimated utility requirements for the unit. This summary includes electric power, cooling water, boiler feed water, steam and foe! estimates . The data presented in this section is preliminary and the detailed engineering contractor should review and revise as necessary.

CONFIDENTIAL PROPERTY OF CHEVRON LUMMUS GLOBAL

TO BE REPRODUCED. AND USED. ONLY IN ACCORDANCE WITH WRJTIEN PER._\l!SS!ON OF


Ch~vron Lu1nmu11 Global

F.quipment: 100- Description Fired Out)·

rot al 75.4

flRS!'STJ\Gl: FLR~ACC 36.0

H-102 SCCONL> ST.'\GI::: FUR~AC !: ltd

H-JO I Al'MOSl'Hl:RIC TOW l:.R FCCL> FURSi\Cl: 9.9

\i;\CUUM TOWU~ fl·.l:.D i'l:RN;\Cl:. 13.2

Comnr('ssors:

Total

(:-JOJA!IVC :vtU ... RG C0\.1PR FSSOR

C-JOIAIB SOUR GAS COMPRFSSOR

Air Cnnl~n;:

Tot:1I

A-IOI Hi' M l £-LASH GAS COOU:k

tl - 10 ·1 (>l.'l:NCH OIL COOL!:R

J\ .J() I 1\l'M lU Wt-.H Rt:.l'U:X /\JR COOU J{

A. -302 A l'M l'OWt.J< O VH!J PRO D_ AIR COOU:.R

!\-JO] l)]J-_'i c.L l'RO J.){ .'C 1· ;\ JR C<X)Ll:R

A-JO.I SOUR CAS COMPRCSSOR l~TrRSTA(i[ COO i T R

A--rn1 TOP R!T \lJX AIR n xur.R

VGO .-\ JR COO! rR

;\-501 OH.T!IAN!7 FR ovrm .A. IRCOOl F.R

;\-502 "l.-\PHTHA STARll.!ZF.R OV HO AIR COOi ER

;\-50] J...:Al'H f H.'\ i'k0UL1C r !\lk COOLt:.R

A-601 CIRCL'LATIO)',. O il AIR COOL!:R (!\utc 61

F.STIMA TEil [;Tll.ITY COl'Sl;MPTIOI' Sl;MMARY

LCMAX RESIDlE HYDROCRACKll'C PLAl'T SHA1'001'C Sll'CIER PETROCHEMICAL CO., LTD.

tTlL. SrlAM. l'OWll<. Al'U COOLll\G WATrn

I.LP Steam, kg/h l.P Steam. kg/h llP Ste:im. kg/h t'u('J,MW r--------+--------+---------t Condensate, kg/h

Proress

[l'\\)tcll

5J.7

2JA

10.6

8..1

11.2

0.4 l\.lPaG

Steam Make Demand

CONFIDENTIAL Property of Chevron Lummus Global To be reproduced, and used, on~ in

accordance with written permission of Chevron Lummus Global

1.5 MPaG .l.9 MPaG

Make Demand !\lake Demand !\.fake

6/ IJ/20 14

Rev_ 0 Page 1 of3

RA-133476

nrw, J.:g/h l)OW('r, kW Cooling W:1ter . (l\ote 2) kg/h

Demantl Denrnnd Demand

17.972

16JmJ

1. 16(_)

252

ll J

163 6]

27

Ch~vron Lu1nmu11 Global

F.quipment: 100- Description

Pumps:

rot al

P-Hll JSJ' LC'MJ\X Rl:.C' YC'LC i'LMI'

P-102 2Nl> LCM."-''< RCCYCLC !'UM!'

P-IOJA/B VR Fl:.Cl> !'UMPS

P-Hl•IA/B l);\0 FCl.:.D l'L'M l'S

P-ltJ 5A/B (llH·. r.;CJI OJL PUMPS

1'-HJ6/\/B I IP \\1AS11 \\1ATrR Pl!MPS

P-107/\/B I IP 1.f.AN AMIS\". PCMPS

P-HJX/\iB \.P l.f.AN A:-..m..:r. PLlMPS

p.J(l l),'\/B \.1P WASH \>,!,A, TF.R Pl'MPS

P-11 0 ])_A,Q I CMAX RFCYCI F Pl M P

P-11 2A 1B IST 1 C\MX RFACTOR SFAI OIL PU MPS

P-11 3;\iB 2J\.l> LCMi\ X RL'\CIORSl: . .'1.L OIL l' LMJ>S

P-lllA/B Ul\O LCM.'\X IU: . .'1.ClOR Stl\L OIL l'UMl'S

P-JOIA/B /\!~. TOW CR Fttl> l'l Ml'S

P-J02A/B A l'M l'OWl;-.J< RU-U~X l'U Ml'S

1'-lO l A/B A l'M IU\'<'l.:.R OVHD l'RODl:C r l'LMJ'S

1'-l04A/B ATM _ l'OWl.:.R J'A l'Ll\1J'S

l'-J05A/B rnr:sr:i. PRODLICTP\IMPS

P-30 6/\/I~ ATM TOWr:R ntHTOMS PL':-..H'S

P-3U 7/\!B IST ATM. TOWFR WATFR PUMPS

P-30 91\IB ~--...,if) ATM. TOWFR W.A TFR PUMPS

P-4(l l;\IB V.AC STRIPPER RTM5 Pll\.fPS

P-4(12AIB V!\C lOWER SLOI' OlL l'LMl'S

P-•IOJA/B VA(' i-owu. SOLR WA!l .R !'UMPS

P-•101A/B LVGOl'LMl'S

l'-•105A/B l-tVGO l'lJt.1l'S

J>-40 6.<\,/I~ W;\S/I (JJL CJRC\JLAl"J( JN Pl.IMPS

l'-40 7A/B \i;\Cl.'L'!l.1 HJWt.I{ H l'!l.1S l'IJMJ'S

P-.ftlX/\iB \.LVtiOPl :MPS

p._5(J IA!I\ !TAN 0 11. AOSORlffR RU U!X PIJ\1PS

P-5(1 2:\il\ u:AN 0 11. AOSORO r:R noTTOMS Prn • .n•s

p._5( J_l;\ ll\ r>F FT1--IA-....:!7FR RFF!.UX Pl'MPS

P-5(141\!B 0...:.APHTHA STAR 1117FR REF! L'X PL'M PS

P-5(1 5;\IB :\l\J>Hl H/'\ S IABJL!Zt.R BlMS l'LMJ'S

P-601A!B Cl\l /\.L \"Sl lRJ\)'..Sl' Ok l OJL l'L1 Mi'S 1t.otc 6~

P-60 2A!B COOLING OIL CJRCL L'\ l !ON l'LMl'S 1J\:utc 6 1

P-60JA!H CAT i\L YSr SL{) )'( )JL l'l.1.\1 PS ('\Ole Oi


LCMAX RESIDlE HYDROCRACKll'C PLAl'T SHA1'001'C Sll'CIER PETROCHEMICAL CO., LTD.


I.LP Steam, kg/h l.P Steam. kg/h llP Ste:im. kg/h t'urJ,l\.lW r--------+--------+---------t Condensate, kg/h

Fired Out)' Proress

0.4 MPaG

Steam !\.fake Demand

CONFIDENT AL Property of Chevron Lummus Global To be reproduced, and used, on~ in accordance with written permission of


1.5 MPaG .l.9 MPaG

Make Demand Make Demand l\.fake

6/ IJ/2014

Rev _ 0 Page2of3

RA-133476

nrw, J.:g/h l)OW('r, kW Cooling W:1ter . (l\ote 2) kg/h

Demantl Denrnnd Demand

7.:>i40

85

85

3 1<4

957

276

2.D9

12--1 0

37

85

27

4ll

2.16

78

11

12 268 3)9

II

125

11 2

l l 19

J 25 58

Rev _ 0 Page3of3


LCMAX RESIDlE HYDROCRACKll'C PLAl'T

SHA1'001'C Sll'CIER PETROCHEMICAL CO., LTD.

Ch~vron Lu1nmu11 Globa l 6/ IJ/2014 RA-133476


I.LP Steam, kg/h l.P Steam. kg/h llP Ste:im. kg/h nrw, 1.:g111 Cooling W:1ter . t'urJ,l\.lW Condensate, kg/h

(l\ote 2 ) l,owrr. k\\'

kg/h 0.4 MPaG 1.5 MPaG .l.9 MPaG

F.quipment: 100- Oescription Fired Out)' Proress Steam !\.fake Oemand Make Oemand Make Oemand !\.fake Oemantl Oenrnnd Oemand

lle:tt Exchan~ers:

rot:tl 4.660 1.694 15.035 J.559 8.243 6.696 29.379 l.550.79J

r-1 04 Hl'-Hl' VA l 'OK SJ'l::A.V\ Gl:'.\.l:.RA!OK 8.243 4J 5 8.678

E-IU7A/B/C .'.1L ~ KG COMl'Rl:.SSOK I ST Sl /1.GI:. l~ l'l:.RCOOL l:.RS 339.286

E-1 118A/B/l' ML .,. RG COMl'Rl:.SSOK 2:"\.V STAG!:. fl\ J'l:.RCOOLl:.RS 692.806

1:· 109 Ml.I • J{G COMl'R l:...'iSOR SPl l.L.H,-\CK COOLl:. I{ 132. 192

l.·110 M!:M l3RANI: F!:l:.D J lb \ l' !--.1{ J . .:- .W .1.5)9

E-111 ST ART-1.'PSlT.AM llT:ATr:R {t-.;me 61 ) .1.)(-H 3.J . .:-6.J

E-11 3 M P/llT VAPOR 'M l-' ST r.AM m :i-; :UJ::!(, U1X .1.1 94

1/-114 M P.'MT VAPOR ('0 01 .f:R 175.469

1/-11 5 :n,.:r> STAGF P'F.RMFATF WATFR COOl FR .lX.04-1

r-116 LF.I\";\ A.'-11".\!F HF.ATF-R 1.694 1.694

r-119 COOi ft'G Oll. HFATFR\l'..:-0tc6\ 11 .517 11.51 7

r-402 LL VGQ \l.,·' f\ l'l:.RCOOLl:-R 2.695

E- IOJ L VGO STl:..'\M Gl:.:'-1:.K.'\ TOR •l.660 229 1.889

HVGO S IEAM Gl:.J\.l:.RAl-OR 12.008 6 10 12.6 18

E-511 1 LL;\~ Oil. AUSORUl:.lJ OV HDCOOL!:R 26.0J I

J-:. )02 Ul-.l:.rll;\~IZl:-ll OVHU THIM C<XJLl:-R 108.7 18

J-:.505 NAl'H It IA J'H<JDl.",{_· J- l "RJ.\1 C<XJL!:R 20.532 E-506 NAPl lT l IA STAnll.17r.R OV r:H l ffAD<.<XllTR 15.0 IX

Column~:

rot al 18.920

1'-301 ATMOSPHERIC TO\\"FR 7.900

!'-302 DIFSFL STRIPPFR J.511(1

!'-303 A1MOSl'HERIC SlRJl'l'l:.R 1.6(1(1

T· llll VACLU~ fOWl:R -1.8711

T-•102 VACUU~ SlRJl'Pl:R 1.0511

1\-'fiscell:meous Varnum Towel' Sedion

Total 34.46 1 J.7J9.6S6

IJ . .JtJI COI L VJ::.LOC IT Y Slb\M .J.lJ9tl

~.tJ· .. .JOI IST lNT rRCONDf.J\Sr.R {1'nte 51 3..t7 1.'.!5lJ

~ .. ff: • .:J.01 ~ND 1:-:TT:RCOJ\Df:NST:R (1'ote 51 LH _JYX

MIAOI .>Rn lNTf:Rc rn.,;or:i-;srn {NNe 51 1_1.LJl)X

M J: •. tol \l!OT!VF STFA'-1 FOR FJFCTOR SYSTEM iN-Ote 51 29.-172

Total l\fa ke/Dem:t nd 75.4 5.1.7 1\1\k I 4.MiO 1.694 15.1135 56.9.J() X.2·0 6.696 2lJJ 79 26.36J 5.290.448

!\et Prmluctinn/((:omumptinn) (75.41 (5.1.71 2.965 (•11.9061 8.2·B 6.6% (29.379) (26.363) (5.2")0 .H8)

CONFIDENTIAL Property of Chevron Lummus Global To be reproduced, and used. on~ in accordance with written permission of



Notes :

ESTINIATED UT IUTY CONSUMPT ION SUMMA l~Y

LC MAX RESID UE HYl>ROCRACKING PLANT SMANOONG SINCIER PETROCl-I EM ICAL CO. , LT D.

NOTES 6/IJ/2 01~ H\ - l.U-176

1. For calculat ion of furnace fired duties . CLG assumes radiant section effic ienc ies of 65% for reaction furnaces and 85% for fractionation furnaces. Convection sect ion heat recovery to be dete1mined by Detail ed Design Cont ractor.

2. BFW demand includes 5% all owance tor blowdown_

3. Cooling water dt,rnand assumes a 32°C supply and a 0°C return tcmpernturc approach. where lirnjted by process outl et temperature; for all other cases the cooling water ret11rn temperature is max imized to 42°C Ac tual rates and return temperat ure to be conli1med by Deta il ed Design Contrac tor.

~- a. Motor efficiencies are assumed to be 95%.

b. Pump etlic iencies are assumed to be 70%.

c. MU + RG Compressor efficiency is assumed to be 87%.

d. Sour Gas Compressor efficiency is assumed to be 80%.

5. Vacuum ejector system utiliti es are estimated based on a th.rec stage ejector system. Final utility n:quirements to be confi1111ed by ejec tor vendor.

6_ Equipment is not used continuously, and are there t(1re not included in power or steam tota ls.

7. CLG recommends emergency power supply for the foll owing equi pment :

a_ HP/MT Flash Gas Cooler. 100-A- IOI (50% o t'the motors)

b. Atm Tower Reflux Air Cooler, 100-A-301 (50% of the motors)

c. Top Reflux Air Cooler. 100-A-40 1 (50% of the motors)

d. Atmospheric Tower Feed Pumps. 100-P-30 1A/l3 .

e. Atmospheri c Tower Reflux Pumps. IOO-P-302Nl3.

f. Atmospheric Tower Pumparound Pumps. I OO-P-304Nl3.

g. Atmospheric Tower Bottom Pumps. 100-P-306NB.

h. Vac uum Stripper Bottorn Pumps. IOO-P-401A/ B.

i. HVGO Pumps. I OO-P-405A/B

j . Vacuum Tower Bottom Pumps. 100-P-407A/ B

k_ LLVGO Pumps. IOO-P-408A/B

CONFIDENTIAL Property of Chevron Li..-nmLJS Global Tnl'l..,.r<>nmrh•N><i ::om''""'"' l'>n~in

Rev O Page 1 oft

Exhibit D


Engineering Design Package

LCMAX RESIDUE HYDROCRACKING PLANT Shandong Sincier Petrochemical Co. Ltd Dongying, P. R. China

Volume llA - Equipment Specifications

September 2014

Chevron Lummus Global Bloomfield, New Jersey Richmond, California

CHEVRON LUMMUS GLOBAL BLOOMFIELD, NEW JERSEY

RICHMOND, CALIFORNIA


UNIT 100

SHANDONG SINCIER PETROCHEMICAL CO. LTD DONGYING, P.R. CHINA

VOLUME llA - EQUIPMENT SPECIFICATION

Contributors: M. Baldassari M. Cassidy B. J. Cooke M. DeAngelis C. DeVito J. Ficarra J. Gonzalez J. Grezzo C. Ilaria

September 2014

P. Jaipersaud T.Johnson S. Lee J. Loganathan W.S. Louie U. Mukherjee M. Nardone S. Ohlmeyer A. Olsen

M. Razuk M. Rickards P. J. Risse J. Ruby P. Santos J. Sauter R. Valente


SHANDONG SINCIER PETROCHEMICAL CO., LTD.

1.0 Introduction

2.0 Equipment List Introduction Equipment List

3.0 Reactor Design Introduction


VOLUME IIA- EOUIPMENT SPECIFICATION

Table of Contents

Equipment No. Page or Drawing No.

LCMAX REACTORS, 100-R-101/102/103 IOO-R-101/102/103 BD-133150

4.0 Vessel Data Introduction

Interstage Separator, 100-V-103 Miscellaneous Welding and Details Nozzle Details Quench Distributor and Collection Pan Details Vortex Breaker and Miscellaneous Details

VR HP/HT Separator, 100-V-104 Miscellaneous Welding and Details Nozzle Details Quench Distributor and Collection Pan Details Vortex Breaker and Miscellaneous Details

DAO HP/HT Separator, 100-V-106 Miscellaneous Welding and Details Nozzle Details Quench Distributor and Collection Pan Details Vortex Breaker and Miscellaneous Details

CONFIDENTIAL Shandong Sincier LCMAX PROPERTY OF CHEVRON LUMMUS GLOBAL

TO BE REPRODUCED, AND USED, ONLY IN ACCORDANCE WITH WRITIEN PERMISSION OF


IOO-V-103

IOO-V-104

IOO-V-106

(I I Sheets)

BD-133155 (5 Sheets)



June 2014


SHANDONG SINCIER PETROCHEMICAL CO. , LTD. DONGYING, P.R. CHINA

VOLUME IIA- EQUIPMENT SPECIFICATION

Table of Contents

HP/MT Separator, 100-V-108 Assembly User's Design Specification Construction Notes Insulation Details Top Manway Spool Skin Point Thennocouples

Catalyst Transfer Vessels, 100-V-601A/B Misc. Welding, Guides , and Instr. for Cat. Trans. Vessels Nozzle Details for Catalyst Transfer Vessels

Vessel Outline Drawings VR Feed Surge Drum DAO Feed Surge Drum VR MP/HT Separator DAO MP/HT Separator HP/LT Separator MP/MT Separator MP/LT Separator HP Centrifugal Separator Membrane KO. Drum MU + RG Compressor 1 st Stage Suction Drum MU + RG Compressor 211

d Stage Suction Drums MU + RG Compressor 3 rd Stage Suction Drums Injection Water Drum Lean Amine Surge Drum Sour Water Degasser Rich Amine Flash Drum LT Oil Flash Drum LP Centrifugal Separator Offgas KO Drum Flash Gas Centrifugal Separator Flash Gas KO. Drum Seal Oil Reservoir Start-Up Heater Condensate Pot Lean Amine Heater Condensate Pot Membrane Feed Heater Condensate Pot

CONFIDENTIAL

Equipment No.

100-V-108

100-V-601A/B

100-V-101 100-V-102 100-V-105 100-V-107 100-V-109 100-V-l 10 100-V-lll 100-V-l 12 100-V-l 13 100-V-l 16 100-V-l l 7A/B/C 100-V-l 18A/B/C 100-V-l 19 100-V-120 100-V-121 100-V-122 100-V-123 100-V-124 100-V-125 100-V-126 100-V-127 100-V-129 100-V-130 100-V-131 100-V-132

Page or Drawing No.



BD-133162 BD-133163 BD-133166 BD-133168 BD-133170 BD-133171 BD-133172 BD-133173 BD-133174 BD-133175 BD-133176 BD-133177 BD-133178 BD-133179 BD-133180 BD-133181 BD-133182 BD-133183 BD-133184 BD-133185 BD-133186 BD-133205 BD-133164 BD-133165 BD-133167

Shandong Sincier LCMAX PROPERTY OF CHEVRON LUMMUS GLOBAL TO BE REPRODUCED, AND USED.ONLY IN

ACCORDANCE W ITH WRITTEN PERM ISSION OF CHEVRON LUMMUS GLOBAL

June 2014



VOLUME IIA- EOUIPMENT SPECIFICATION

Table of Contents

Cooling Oil Heater Condensate Pot LT/MT Oil Surge Drum Atmospheric Tower Reflux Drum Atmospheric Tower Overhead Product Drum Sour Gas Compressor I" Stage Suction Drum Sour Gas Compressor 2"d Stage Suction Drum Vacuum Tower Btms. Steam Drum Lean Oil Absorber Reflux Drum Deethanizer Reflux Drum Naphtha Stabilizer Reflux Drum Deethanizer Water Draw-off Pot Transport Oil Surge Drum Cooling Oil Surge Drum Fresh Catalyst Transport Pot Catalyst Inventory Holding Bin Catalyst Slop Oil Drum Oil Drain Surge Drum FCTP Liquid Overflow Pot Spent Catalyst De-oiling Bin

5.0 Column Data Introduction

HP Amine Absorber & Wash Column LP Amine Absorber Flash Gas Amine Absorber Atmospheric Tower Diesel Stripper Atmospheric Stripper Vacuum Tower Vacuum Stripper Lean Oil Absorber Deethanizer Naphtha Stabilizer

CONFIDENTIAL

Equipment No.

IOO-V-133 IOO-V-301 IOO-V-302 IOO-V-303 IOO-V-304 IOO-V-305 IOO-V-403 IOO-V-501 IOO-V-502 IOO-V-503 IOO-V-504 IOO-V-602 IOO-V-603 IOO-V-604 I OO-V-605A/B/C IOO-V-606 IOO-V-607 IOO-V-608 IOO-V-609

100-T-IOI IOO-T-102 IOO-T-103 IOO-T-301 IOO-T-302 IOO-T-303 IOO-T-401 IOO-T-402 IOO-T-501 IOO-T-502 IOO-T-503

Page or Drawing No.

BD-133169 BD-133187 BD-133188 BD-133189 BD-133190 BD-133191 BD-133196 BD-133192 BD-133193 BD-133194 BD-133195 BD-133197 BD-133198 BD-133199 BD-133200 BD-133201 BD-133202 BD-133203 BD-133204

BD-133207 BD-133208 BD-133209 BD-133210 BD-133211 BD-133212 BD-133213 BD-133214 BD-133215 BD-133216 BD-133217

Shandong Sincier LCMAX PROPERTY OF CHEVRON LUMMUS GLOBAL TO BE REPRODUCED, AND USED, ONLY IN


June 2014

overall yield of products (volume)

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