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1. HSD using the hydrocyclon to pre-separation of liquid:
2. Choice least
3. H2S pressure partial
Standard on NACE: 0.3 kPaA H2S partial. In TLDD project well 7P, H2S partial = 0.646 kPaA > NACE: 0.3 kPaA
So that, they combined well 7 with non-H2S well, H2S total is 0.044 kPa < NACE standard.
And they can using Carbon steel (H2S
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9. Well Unloading Line: to be provide from test header to close drain which can be used during initial start-up
10. TIA must be located Min 2000mm from Choke valve to minimmize temperature efffect
11. Vessel or equipment have minimum temperature so low, it's connect with a short good materia(SS)l by flang
So that, Good material (SS) must minimum 5m from equipment to other material ( ref to P&ID 1066 of TLDD pro
12. On PSV:
Liquid: Velocity Head of downstream PSV must be at 10% Design Pressure or smaller Overpressure.
Pressure Drop on Suction Head must be < 3% inlet pressure.
13. Choice the separator depend on mass flow, turndown(Max flow/minimum flow)
14.Min Flow in Pump
All of centrifugate pump have the Min Flow system(may be PSV as back flow) or Min flow with RO & Ball valve.Purpose: It's protect the pump that on case the block outlet the discharge pump. RO + Ball valve is the system w
15. Explanation the why Crude Heater Outlet isn't using NACE material ( TLDD):
Because, Crude Heater is collection all of wellhead production, so that, total H2S vapour pressure composion < 3
Then, TLDD will be shutdown all of wellhead ( signal is based on AIA on Pig launcher near production pipeline)
16. PSV coefficient of discharge
API 526 using factor = 0.7 to 0.75 based on the actual flow area(NB-18)
Pilot valve available the factor = 0.95 + range range based on the actual flow area
ASME VIII (ASME BPVC) are 90% of the observed values (chapter 3.6.3 "Pressure relief and effluent handling pre
Noncertified valves design for ASME VIII service can have observice coefficientsas high as 0.85.
So that, generally availabe in only a few small sizes, with threaded connection.
17. Insulation Kit (piping)It's special Item on P&ID, so using on break material(interface of two different material that can corrosions). exa
CS & SS. IT's using gasket to avoid direct contact between flanges & sleeve & washer to avoid contact direct
bulong to flange.
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18. Filter Coalescer
Choice the filter coalescer:
If an organic dispersed phase 'wets' organic that is plastic or polimeric hydrophilic ( like water) (oil is contino
Else an aqueous dispersed phase preferably wet inorganic media, such as metal & glass (like oil)
Coalescer work better in laminar flow; increse contcting time wire mesh & streamline
Velocity so high overcom surface tension forces and strip droplets out of the coalescer medium
19. All of well is order Miocene type have to sand detector. Because, Miocene is lower water deep and contain
20. PCS will be control the test well flowline (each of well at a time) based on sequence.
21. On bypass PSV always have a lock close (ball valve), to assure that the operator inadvertent opening th by22. Standard for deflector vessel:
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(ref. 236 page-Pressure Vessel Design Manual
23. Follow the Pipieline: DNV F101 cerfify that with all of pipeline >= 8 in, wall thickness minimum = 12 mm.
24. Follow the Pipeline : DNV F101 certify that with all lining(cladding) thickness must be not less 2.5 mm. (C-400
25. Follow the Pipeline: DNV F101 certify that "clad" if the bond between base and ladding material is metallurgi
and "lined" if bond is mechanical. ( Page 51)
26. Fracture toughness testing of the Base material(BM) and the Weld Metal(WM) welded linepipe, shall be conas part as qualification (Table 6-12, table 6-13). The measured fracture toughness of the BM and the VM shall, as
Have CTOD value of 20 mm, when tested at the minimum design temperature. The testing shall be performed in
Appendix B A 800. Testing is not required for pipes with tnom
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flame mixed.
39. ASME 8 Liquid relief valve: any liquid pressure relief valve shall used at least NPS 1/2 (DN 15)
40. Bypass valve using to :
Prevent working at shut-off point: head is maximum and zero flow rate through valve
Using in boiler-feed, It can decrease the temperature which raise because friction.
Example:
When you increase the orifice (control valve), Q will be increase and H is decrease
From this formula, H is decrease then delta T is decrease
41. Flare: The LPG or fuel gas shall be used to purge the flare headers during start-up.
42. Flow Assurance (No touch time): No touch time may be smaller the shutdown time
Example: When you shutdown pipeline in 6 hr, the 3 hr from initial is not formation the WAT
there for, operator can not touch any thing to system (No touch time) but, after 3 hr, WAX is formatiom
It's not the no touch time.
43. Corrosion protection: Methanol & MEG can prevent the corrosion, and MeOH will prevent corrosion better
but, MeOH shall be using at < 60oC, because above 60oC MeOH is evaporated and is not enough the MeOH liqui
to protecting the system
44. Flow Assurance: Type of slug
1) Hydrodynamic: It's slug in horizontal pipeline(not change the elevation), cause of gas velocity muc
2) Terrain Slug: Is slug formation because the changing of elevation or dip
3) Severe Slug (Based of Riser Slug) is slug formation cause of circummulate at based on riser
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Riser Slug (P.782)
45. Way to Eliminate severe slug:
1) Pipeline route slopes up to the base on of the riser
2) Gas injection into the base of the riser continually lifts liquid out of the riser, preventing the built-u
Noted: why increase the gas at base on riser can prevent the slug?
If gas mass flow rate is inscrease then Vsg is inscrease and Vsg/Vsl is insecrease sao that LHS > RHS a
3) Choking
A fourth method is to install a control valve on the top of the riser. On shutting this valve
a position is reached whereby the frictional pressure drop across the valve acts to stabilize
the gas-liquid flow up the riser. Any acceleration of liquid up the riser due to a decrease
in liquid head in the riser (caused, say, by a gas bubble entering the base of the riser), is
counteracted by the increase in frictional pressure drop across the valve as the liquid
accelerates. The penalty of this way of eliminating severe slugging is that the pressure
drop across the valve will be of the order of a riser height of liquid, thus imposing a
significant extra back-pressure on the system at all times.
46) Slug Catcher
A preliminary design approach was used to estimate the slug catcher size based on the flexibleriser volumes. It was assumed the slug catcher was designed to contain 60% of the liquid in both
By assuming that 60% of this total liquid will fill up 100% of the slug catcher volume
47) Flow Assurance: Turn-Down Case:
The main purpose of this study is to identify the minimum turn down rate required
to achieve a minimum fluid arrival temperature higher than the pour point temperature
Turdown rate may be take of 30 - 90% normal flow rate (so important with oil fluid)
48) Flow Assurance: Ramp-up Case
Purpose of this study was to investigate the liquid surge associate with this operation
Ram-up will be simulation were 'restart' from the previous turndown runs of 25%
Model: ramup from 25% - 100% in 20s.
49) Insulation Pipeline: why is not use the Poly ethane for pipeline insulation:
Polyethylene (PE or HDPE) can handle temperatures up to 80 Celsius and is often used in
direct burial and long term submerged applications for industrial and telephone applications.
Advantages: Very low water absorption and good resistance to a wide range of chemicals
Disadvantages: Very stiff in cold weather and not as resistant to abrasion as polyurethane
Recommended use: Permanent installations, unless high temperature or high contamination
is involved.
50) Table material properties to choice
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51) Flow Asurance: Shutdown
Purpose to investigate the time to reach the pourpoint temperature of the fluid
Model: Flow rate shall be decreased from 100% to no flow in 20s by using a vlave
Noted two case: shutdown for depressure and shutdown for blowdown (refer Bien Dong Flow Assura
52) Flow Assurance: Restart Case
Purpose to investigate the liquid surge associate with this operation
Model: Open valve quikly about 20s
Noted: usually initial properties from shutdown case.
53) Flow Assurance: "What's "near horizontal" and near vertical"
The term "near horizontal" is used in this guide to denote angles of -10 degrees to + 10 degrees from
The term "near vertical" is used in this guide to denote upward inclined pipes with angles from 75 to
54) Flow Assurance: Correct method applicate for FA Model
Chara
Vertical two phase flow, region low, intermediate and hi
Method
Dun & Ros (D-R)
Orkiszewski (OR)
Two Phase flow pressure drop in vertical pipe, this metho
pressure drop in flowing and gas lift
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Extension of Begg & Brill Original with no-slip holdup, the
55) Flow Assurance: Choice the model
1
2
AGA & Flanigan (AGA)
Oliemans (OL)
Gray (GR)
Xiao (XI)
Begg & Brill Revised (B-BR)
Mukherjee & Brill (M-B)
Govier, Aziz & Fogarasi (G-A)
OLGAS-89,92 (O-89, O-92)
Ansari (AN)
Researching in small diameter vertical conduits, study flo
flowrate, gas liquid ratio.
Study two phase in horizontal and inclined pipe. The mod
of up to +/-90
BJA for Condensate (BJ)
Hagedorn & Brown (H-B)
Begg & Brill Original (B-BO)
Well of the method study of pressure drop in two phase i
Developed following a study of pressure drop in wells proResearching from SINTEF laborary with operation conditi
Operating pressure: 20 and 90 barg, gas velocity 13 m/s,
were studied in addion upwards and downward a hill sec
Develop as part of the Tulsa University Fluid Flow Project
partterns for upward two phase flow. Small diameter/ lo
Behavior by experimental, It's good method for near hori
Reasonbly good predictions of the various flow regime tr
each revision in near vertical flow
This correlation was developed by H. E. Gray of Shell Oil
which are predominantly gas phase. Flow is treated as sin
pipe wall. It is considered applicable for vertical flow cas
3 , the condensate ratio is below 50 bbl/mmscf, and t
The Xiao comprehensive mechanistic model was deveprogram. It was developed for gas-liquid two-phase fl
pipelines. The data bank included large diameter field dat
pipeline data bank, and laboratory data published in liter
and compositional fluid systems. A new correlation was p
friction factor under stratified flow. Small diameter/low p
Baker Jardine & Associates have developed a correlat
with a no-slip liquid volume fraction of lower than 0.1. M
The AGA & Flanigan correlation was developed for horizo
The Taitel Dukler flow regime map is used which consider
intermittent, annular dispersed liquid, and dispersed bu
The Oliemans correlation was developed following th
pipelines. The model was based on a limited amount
operating at pressures of 100 barg or higher.
Taitel-Dukler
Taitel and al (Aviv) Barnea
Noted
1. Ussually
2. Normal
3. Not much
Near Horizontal Low Gas-Oil Ratio
Pressure Drop
Near Horizontal Gas/condensate
Begg & Brill
Eaton-Oileman is good
All of method are poor
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3 Both Gray and Hagedo
4
5
6
1
2
3
4
5
6
1
2
56) Flow Assurance standard: Pressure drop:
For plant piping: 0.2 - 0.5 / 100 ft
For gas/condensate pipeline: 10 - 20 psi / mile
Noted: Pipephase 6.02 does not properly account for acceleration losses and is not suitable for use in
57) Flow Assurance: Distinguish the tyype of fluid
Wet gas: Gravity: 40 - 60 oAPI, GORs more than 50000 SCF/STB
Retrograde Gas: Gravity : 40 - 60 API, GORs 3300 SCF/STB to 150000 SCF/S
Volatile Oils: Gravity: 40 API or higher, GOR = 2000 to 3000 SCF/STB
Black Oils: Gravity below 45 API, GOR < 2000 SCF/STB
58) Flow Assurance: Assumed heat transfer cofficient for subsea flowline ( follow chevron)
Nonburied Pipeline without concrete
Application
Hagedorn and Brown i
Nothing is good; Begg
Liquid Hold-up
All available methods
correlation is better th
Near Horizontal Gas/Condensate Lines
Beggs and Brill (Moody
lines nothing is accurat
If gas velocities are hi
use Beggs and Brill (M
careful because the ho
factor of 10 in error in
Inclined Up
Everything is poor. U
(Moody), but answers
Inclined Down and Vertical Down
2Wells
Risers
Buried Pipelines
Concrete Coated Nonburied Pipelines
5-10
Everything is poor. U
(Moody), but answersInclined Down and Vertical Down
Inclined Up
Near Vertical Gas/Oil
Near Vertical gas/condensate
U-value BTU/hr/ft2/degF
20-40
1-3
3-5
Flow Regime
The Taitel-Dukler flow regime map is as good as OLGAS for near horizontal f
of the slug-dispersed bubble boundary. This boundary is very poorly predicted. I
it is recommended that a value of ~10 ft/sec be used as the superficial liquid vel
bubble transition rather than the Taitel-Dukler prediction.
The Taitel-Dukler-Barnea map for near vertical flow is also as accurate as
Near Vertical Gas/Oil
Near Horizontal Low Gas-Oil Ratio Beggs and Brill (Moody
The most accurate me
Hagedorn and Brown i
Near Vertical Gas/Condensate
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59) Properties defend the pressure & temperature
Gas
Temperature
Oil
Temperature
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60 Flow Assurance: Why dehydrate on platform PQP ???
Notice: HYDRATE FORMATION TEMPERATURE SHALL BE DECREASE (MAY BE NEGATIVE) FOLLOWING THE WA
example:
Because this, dependent the lowest temperature pipeline (operating: shutdown, restart, blowdown,depressure
and request the treatment the dehydrate zone.
Reference Bien Dong PQP platform:
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61. Sonic velocity in multiphase
- Sonic velocity in multiphase always lower than single phase, experimental: Vsonic = 30 - 40 m/s in 0.
62. Flow Assurance: Criterion pigging (when we shall be pigging?)
When wax thickness = 2 - 3 mm or loss of 4- 6 mm then need to pigging ( NTNU- wax deposition Models - Maste
63. Flow Assurance: Avoid compromising pig selectio and operation
1. Pipe: - Constant bore if can
- Maximum diameter pipe deviation and Any internal diameter chan
2. Valve: - Valve always full bore and concentric with pipe3.Tee/Offtakes - Branch connection > 50% internal pipe should be barred
- Branch have to installate above centerline to avoid deposit being pu
4. Bend - Minimum bend radius
64. Flow Assurance: How is stability flow in flow as, defined in exit of flow line
stability index = (max liquid flow - min liquid flow)
average liquid flow
65 Insulation: SPU properties refer to ASTM C518
66. Corrosion: Rul of Thumb for CO2 corrosion:
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C.de Waard and D.E.Milliams give a rule of Thumb, if CO2 pressure partial > 2 bar then CO2 corrosion
CO2 pressure < 0.5 (7 psia) bar, CO2 corrosion can acceptable.
67. Vent Flare system: Probleme, closed drain vessel is handle blowdown and relief flowrate so that gas outlet c
Probleme: How many liquid that permit to drawn-out by gas? (kg/h, m3/s)?
PTS 80.45.10.10 only handle dry gas in vent stack. But can permission gas load () is < 0.07
68. Slope line from drum vessel to flare:
PTS 80.45.10.10 page 46 refer slope 1:200 to 1:500 for correct slope in flare.
69. Flow Assurance Liquid hol-up to liquid inventory system
From GPSA 17 chapter (Eq. 17.57): IL= 28,58. H le.d2.Lm
Lm: Length of line (miles)
d: internal diameter of pipe, inch.
70. Flare system:Velocity at vent tips is enough high to jet gas entrain by air (API 521-2007 page 66)
http://localhost/var/www/apps/conversion/tmp/nghia/A.%20Phuong/A.%20Phuong/Petronas%20standard/PTS_D&Ec/80451010.pdfhttp://localhost/var/www/apps/conversion/tmp/nghia/A.%20Phuong/A.%20Phuong/Petronas%20standard/PTS_D&Ec/80451010.pdfhttp://localhost/var/www/apps/conversion/tmp/nghia/A.%20Phuong/A.%20Phuong/Petronas%20standard/PTS_D&Ec/80451010.pdfhttp://localhost/var/www/apps/conversion/tmp/nghia/A.%20Phuong/A.%20Phuong/Petronas%20standard/PTS_D&Ec/80451010.pdf8/13/2019 New Understand
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80. Flare system: (Velocity at tips): Max. velocity at the tip should not exceed a Mach 0.5 but velocity existing fla
81. Flare: Pressure drop: Pressure drop in flare usually = 0.2 bar, minimum pressure at flare not smaller 0.7 bar (
82. Wax consider: Rule of thumb heavy oil is considered all liquid petroleum which has API gravity betw
83. Flow Assurance standard for water contents in pipeline in sale gas: 7 lb H2O/MMscf, refer "sai ..\Flow As
84. Important worst-case in flow assurance:
Maximum liquid hold-up in pipeline: Higher pressure, lower temperature, low flow.
Pigging: Worst-case at high liquid hold-up in pipeline. (MT take of low flow, low temperature (at low
Hydrate: Worst-case at high pressure ( affect much to hydrate form)
85. Flow assurance: Relationship between pressure drop, velocity & flow rate
Not correct when thinking that: If you decrease flowrate(or increase size of pipe) then will be decrea
Because: Pressure drop = friction loss (velocity) + Block of liquid hold-up, when decrease flowrate so
If loss of liquid hold-up > benefit of friction loss then pressure will be decrease.
86. Purge Flare
Flare have to continuously by process fluid (may be extract from flare header) to keep always exites
A check vale is require when inert gas is used as purge gas
83. HTGC (High temperature gas chromatography) & SFC (supercritical fluid chromatography): A method in labor
carbon atoms.
http://localhost/var/www/apps/conversion/tmp/pipeline/Wax/FA%20and%20sour%20gas%20in%20natural%20gas%20production.pdfhttp://localhost/var/www/apps/conversion/tmp/Flow%20Assurance/Hydrate/Saied-Handbook-of-Natural-Gas-Transmission-Processing.pdfhttp://localhost/var/www/apps/conversion/tmp/Flow%20Assurance/Hydrate/Saied-Handbook-of-Natural-Gas-Transmission-Processing.pdfhttp://localhost/var/www/apps/conversion/tmp/Flow%20Assurance/Hydrate/Saied-Handbook-of-Natural-Gas-Transmission-Processing.pdfhttp://localhost/var/www/apps/conversion/tmp/pipeline/Wax/FA%20and%20sour%20gas%20in%20natural%20gas%20production.pdf8/13/2019 New Understand
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= 99 barg. So, It's boundary of the class 600#.DD choice class 900# for safety.
of not requiring the ESD
pressure. In output(running of pig piping ) is drop pressure and temperature
WHP) will WAT formation. Need the evacuated/drain to eliminated the
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e. But to fall the cost, It's connect this pipe with other material (CS)
ect)
hich choose in TLDD project due to cheaper than PSV.
kPa, not using NACE. But if each of well is failure and H2S greater 3kPa
sure)
mple
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ustly phase)
larger sand quantity.
pass( throwing continuose the HC to flare or environment)
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Book)
or pagd 51)
cal &
ucteda minimum,
according
C (Flow Assurance Deepwater 7-15)
peline may be take longer.
dent of the downstream pressure (Flow Assurance Deepwater 8-9)
system.
effect so much to heat)
and can assume = wall temp.
ll sao that fluid temp. is decreased to minimum ambient so
e to 0.5 ratio 2 for exactly simulaion (but not obligate)
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EG
d
greater than liquid and formation slug
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p of liquid and subsequent seal to the gas flow
d decrease or preventing the severe slugging
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nce)
horizontal.
+ 90 degrees from horizontal.
teristic of Method
h gas throughputs respective
d can accuracy 10% two phase
Sequence for using
3
2
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friction factor is changed from standard smooth pipe model
1", 1.25", 1.5" nominal size with varying liquid, gas
el inclines flow both upwards and downwardsat angle
nclined flow
ducing gas and condensate, GOR = 3900 - 1170000 scf/bbln is similar field conditions, test 800 m long pipe and 8" DN
liquid velocity up to 4 m/s, inclination angle between +-1
ion ahead of a 50 m high vertical riser. Accuracy is likely Taitel
(TUFTP), model of flow characteristics of predicted flow
pressure good for near vertical.
izontal (only near horizontal)
nsitions, and the accuracy of the predictiona has improved with
ompany for vertical flow in gas and condensate systems
gle phase, and water or condensate is assumed to adhere to the
es where the velocity is below 50 ft/s, the tube size is below
he water ratio is below 5 bbl/mmscf.
loped as part of the TUFPP researchow in horizontal and near horizontal
a culled from the AGA multiphase
ture. Data included both black oil
roposed which predicts the internal
ressure data
ion for two phase flow in gas - condensate pipelines
ethod is similar Oil-man
ntal and inclined two phase flow of gas-condensate systems.
s five flow regimes, stratified smooth, stratified wavy,
bble.
study of large diameter condensate
of data from a 30", 100 km pipeline
3
1
1
3
3
1
3
3
2
2
3
2
1
1
ethod
(Moody) is good)
for relative high velocity.
for low velocity
8/13/2019 New Understand
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rn-Brown are good.
flare system design as a result
B
s good
and Brill (Moody) is fair.
are poor.The Eaton holdup
an the other methods.
) is usable for low GOR
e for gas/condensate
h, use no-slip; otherwise
ody). The user must be
ldups can be a
some cases.se Beggs and Brill
may be suspect.
se Beggs and Brill
may be suspect at times.
low with the exception
this method is used
city for the slug-dispersed
LGAS.
) is O.K.
hod is no-slip.
pretty good.
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Pressure
Pressure
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ER CONTENT IN FLUID
), engineer will be analysys water content in fluid flow in pipeline
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- 0.8 void fraction at 1.4 - 1.6 bar
thesis)
e should be made within a transition piece of 1:5 slope.
hed in branch.
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will be serious
n carry the liquid to vent amospheric (liquid carry-over)
.
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re do not exceed a Mach No. 0.7
inimum).
een 10 - 21.9 and extra-heavy oil less than 10oAPI (Berberii, 1998) (page 9)
urance\Hydrate\Saied-Handbook-of-Natural-Gas-Transmission-Processing.pdf
and high pressure)
e velocity and decrease pressure drop. SO FAULT
riction loss decrease but pressure loss for liquid-holdup inscrease
as in flare to avoid exploration by air enter flare system.
ary define WAX contents, It enable identification of wax up to 100
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Check P&ID
Open drain tank:
Heat tracing pipe
Electrical heat on bottom open drain tank to prevent WAX
Have over flow and vent pipe. Vent pipe ensure that free gas/air into open drain
Rodding point to supply to removal of blockages
2. Sand probeThis is equipment to monitor the erosion found in process systems, in oil & gas sand probe using to mo
The distance from chocked valve to sand prob
3. Flow straighteners (conditioners)
Flow straighteners eliminate rotation of fluids and steady velocity profile of fluid flow, enable to shorte
standard. Individual types of flow straighteners differs by construction design ( Zanker" perforated til
square sections, Etoile" 8 radial lamellas arranged in the star-shape) and its use. Use of flow straight
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LINK: https://docs.google.com/viewer?a=v&q=cache:tEngwITn1msJ:www.onicon.com/pdfs/0497-
3_Flow_Straightener_Catalog_Sheet_0112.pdf+flow+straightener&hl=en&gl=vn&pid=bl&srcid=ADGEES
YOQWCaWM82oNJW9yiJfn1gmd_tJLcDGm_yoHBenFbhX-6KxVr9BHHaaVEz3vq7lVo4a5XcBLI&sig=AHIE
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Rodding (tm che lc cn bn)
itor erodes of sand in oil
e is min 2 ft (610 mm) (ANZ P&ID note)
length of inlet piping in front of primary element, especially behind adapting pipes not stated in the
le+bundle of channels, Sprenkle" 3 perforated tiles, bundle of pipes, AMCA seam of channels of
ner helps to achieve higher stability and accuracy of measured flow.
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jX2NZgXKbuTkgpSqxfz6Xtvx7iRjjXjsyniXU6p7pMptWkkttKNHwGFskwBH-
bQSMe4WBFi5RkZRaJOWVOSTbopOeA
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1. Hp th: nh hng dung mi n qu trnh hp thCng nng cht b hp th yu cu t c, nu lng dung mi tng ln th gim c kch thc
Nu gim lng dung mi i hi din tch tip xc hai pha (kh v dung mi) nhiu hn hay kch thc
C th quan h bi phng trnh sau:
G = Ky.F.Ytb (l phng trnh truyn cht c bn)
Ky: h s chuyn khi tnh theo pha kh, Ky s khng i nu nhit v p sut khng i,
Ytb: l ng lc trung bnh ca qu trnh.
y = 1/Ry: h s cp khi ca qu trnh, Ry l tr lc trong pha y (pha kh)
m: h s phn b nng , m = /P (: l hng s henry) Pi = xi
Nu cu t d ha tan th m/x rt nh Ky = y
Nu cu t kh ha tan th m/x rt nh Ky = x
ng lc trung bnh logarit
Thay i ng lm vic khi thay i ng lc trung bnh ca qu trnh
BA4 di nht nn ng vi ng ng lc cn bng nh nhtV G v Ky k i nn F.Ytb khng i, do BA ng vi F nh nht v ng lc trung bnh l
BA4 nh nht nn F(din tch tip xc) ln nht
M A = Gtr/Gx, B = Yc - (Gx/Gtr).Xd
Gtr : lng kh tr khng i
Gx: lng dung mi vo thit b hp th
Phng trnh ng lm vic hp th: Y = AX + B
Do , BA4 nghing nht 9(gc nh nht) nn Gx: lng dung mi nh nht
BA c gc nghing ln nht lng dung mi ln nht
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Kt lun chn dung mi:
Dung mi t thit b ln, dung mi nhiu thit b nh gn
2.Hp th: nh hng ca nhit v p sut n hp th
nhit tng th h s henry tng (phng trnh henry) do cn bng chuyn dch v pha trc tung
ng AB s khng i(ng lm vic ph thuc thnh phn kh, lng dung mi v din tch tip xc
ng cn bng ph thuc p sut nhit )
Nu nhit cng tng,ng lc qu trnh cng gim n t3 ct ng lm vic s khng th hp th
Do nhit cao xu cho qu trnh, tuy nhin nhit 1 khong no y li c li v ma st gim n
p sut tng lm m gim ( m = /P) ng cn bng di chuyn v pha trc honh hayNhng p sut tng s km tng nhit nh hng xu n qu trnh nn p sut cao ch dng h c
Kt lun: Hp th tt p sut cao v nhit thp(cho php), l nguyn nhn ngi ta mong m
Qu trnh hp th l s ha tan nn c s sn sinh nhit
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thit b
s ln hn
hi ng lc khuych tn, thm thu qua mng tip xc s k i)
Pi= xi
n nht
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Tt nht v c th t nng Yc thp hn (hay dng kh tinh khit hn)
)
c (k th t c Xc) nng cui.
n tng d khuych tn.
ng lc qu trnh tng hp th tth kh ha tan CO2, CO
n lu cht vo thp hp th nhit im sng (dewpoint)
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Number
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
1819
20
21
22
23
24
25
26
27
28
29
30
Flow assurance (
WAT deposit)
General
Corrosion
Corrosion
Corrosion
Cathodic reactionPosition terminal(cc dng): where electron flow to, and redu
+ 4H+4e-= 2H2O ( if environment is acide base)
ion strength
The ionic strength of a solution is total of the concentration of inumber of ion. Exa.: Ionic strength of a mixed 0.050 mol d
I = 1/2((2 (+1)2 0.050) + (+1)2 0.020 + (
shear rate
The velocity gradient measured across the diameter of a fluid-f
change of velocity at which one layer of fluid passes over an ad
parallel plates that are 1.0 cm apart, the upper plate moving at
lower plate is not moving and the layer nearest the top plate is
cm/sec. The velocity gradient is the rate of change of velocity w
gradient with shear rate (v1 - v2)/h = shear rate = (cm/sec)/(cm
FluxIt's abbracation to taking that a unit (mass, heat) tranfer a un
capacity of diffusion of mass tranfer on 1m2on 1 second. D: diff
Anodic reaction Negative terminal(cc m): where electron flow from, and oxi
Title Abbrevation
porosityFlow assurance The concentration of oil in a wax deposit, oile in 3D-deposit ( Fi
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2 BASIC THEORY OF GROUNDWATER FLOW
2.1 Introduction and terminology
Three types of aquifers are considered (see Fig. 2-1):
- the confined aquifer, confined at top and bottom by impervious layer
- the unconfined or phreatic aquifer, which has a free water table, and
- the semi-confined or leaky aquifer, which is receiving water from or losing water to
overlying or underlying aquifers through a slightly pervious top or bottom boundary
2.2 Darcy law
(2-1)
(2-2)
The true pore velocity can be obtained by dividing the Darcy flux with the porosity n of the soil medium
(2-3)
Flow in subsurface waters can be divided into unsaturated and saturated flow. The unsaturated flow is
Chapter 2 regional groundwater flow is discussed. Regional implies that we are interested in aquifers or
much larger than their depth. Moreover, we consider porous aquifers only, as opposed to fracrured-roc
The variable to be calculated in the models is the piezometer head in the cases of confined and leaky
aquifer and the water table elevation in the case of unconfined aquifer. For both variables the term
head (H) or hydraulic head is used throughout the book. Flow is caused by gradients of the head.
In confined aquifers we usually utilize the concept of transmissivity which is the product of hydraulic
conductivity K and the aquifer thickness b, i.e. T = Kb and its unit is usually m2 d-1. Transmissivity is
discussed in detail in Chapter 3.
By a series of sand column experiments Henry Darcy established in 1850's that, for a given type of
sand, the volume of discharge rate Q (m3 s-1)is proportional to the head difference DH and to the cross-
sectional area A (m2) of the column, but is is inversely proportional to the distance DL of the flow path.
Discharge Q can be calculated as
where the proportionality coefficient K (m s-1
) is called the hydraulic conductivity of the soil. The
average flux can be obtained by dividing Q with A. This flux is often called Darcy flux qW:
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Eq. (2-3) implies that the true velocity of the water molecules is larger that the average velocity becaus
Negative sign in Darcy's law?
The reason for the negative sign in Eqs. (2-1) or (2-2) is that water is flowing from higher to lower poten
Similarity between Darcy's law and other laws of physics
It is important to recognize the similarity between Darcy's law, Fourier's law of heat
transfer and Fick's law of diffusion flow.
Fourier qH= -K H DT/Dz
where qHis thermal flux (J m-2
s-1
) across a plate, KHis thermal conductivity of the plate (J m-1
K-1
s-1
), DT
Fick's law qC= -D DC/Dx
where qCis the diffusive flux (mol m-2
s-1
), D is diffusion coefficient (m2s
-1), DC is
concentration difference (mol m-3
) between two points located at a distance Dx (m)
from each other.
Similarity between Darcy's law and other laws of physics
It is important to recognize the similarity between Darcy's law, Fourier's law of heat
transfer and Fick's law of diffusion flow.
Fourier qH= -K H DT/Dz
where qHis thermal flux (J m-2
s-1
) across a plate, KHis thermal conductivity of the plate (J m-1
K-1
s-1
), DT
Fick's law qC= -D DC/Dx
where qCis the diffusive flux (mol m-2
s-1
), D is diffusion coefficient (m2s
-1), DC is
concentration difference (mol m-3
) between two points located at a distance Dx (m)
from each other.
2.3 Dupuit-Forcheimer assumption
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In the regional groundwater models it is assumed that flow is essentially horizontal which implies that d
Dupuit or Dupuit-Forcheimer-assumption. This is not true in the vicinity of e.g. pumping wells, in region
aquifer thickness, in the vicinity of infiltrating surface water bodies, and in regions of strong groundwat
vertical disturbancies, however, will usually become negligible over a horizontal distance of the order o
aquifer thickness (Kinzelbach 1984).
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.
iscussed in Chapter 7 and therefore, in
parts of aquifers with horizontal extensions
k or karst aquifers.
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only the pore volume contributes to flow.
tial, i.e. the direction of flow has the opposite sign as compared with the potential gradient.
is temperature difference (K) and Dz is the thickness of the plate (m).
is temperature difference (K) and Dz is the thickness of the plate (m).
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H/dz = 0. This is called
s with strongly varying
r recharge. These
magnitude of the
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