production petroleum software (1)

7/21/2019 Production Petroleum Software (1)

1/48

PROSPER WELL

MODELLING

FUNDAMENTALS


2/48

PREPARED BY

Ahmed mohamed Abdullah

Refaat Galal Abol Fotoh

Nader Ali Fahim

Hesham Ahmed Abo-zaid

Yahia Ali Shawky


3/48

CONTENTSIntroductionWell Modelling Fundamentals

Setting up a well modelPVT ModellingIPR modelling

VLP modellingVLP / IPR matching and model validationConclusions


4/48

PETEX (PETROLEUM EXPERTS)

Started business @ 1990 in the UK

Developing a set of petroleum engineeringsoftware tools.

model oil reservoirs, production and injection

wells and surface pipeline networks as an

integrated production system.


5/48

SOFTWARE PACKAGES


6/48

IPM PACKAGE

The engineer is able to design complex field models.

The Reservoir, Wells and Complete SurfaceSystems model, having been matched for

production history, will accurately optimize the

entire network and run predictions.


7/48

IPM PACKAGE


8/48

IPM PACKAGE

GAPenables the engineer to build representative

field models, that include the reservoirs, wells

and surface pipeline production and injection

system.

MBALpackage contains the classical reservoir

engineering tool, using analytical techniques to

analyze the fluid dynamics in the reservoir.


9/48

IPM PACKAGE

PVTPallows tuning of Equations of State (EoS)

to match laboratory data. The tuned EoS can

then be used to simulate a range of reservoir and

production processes, which impact equipment

sizing and reservoir recovery.

REVEALis a specialized reservoir simulator

modeling near well bore effects including mobility

and infectivity issues. Thermal and chemicaleffects are modeled rigorously.


10/48

PROSPER

PROSPERis designed to allow the building of

reliable and consistent well models

Design and optimize well completion

Tubing size

Artificial lift method

IPR model


11/48

CONTENTSIntroductionWell Modelling Fundamentals

Setting up a well modelIPR modellingVLP modelling

VLP / IPR matching and model validationConclusions


12/48

WELL MODELLING

FUNDAMENTALS Well modelling defines the pressure/rate relationship tofacilitate: Well design Predicting well performance Identify well performance sensitivity to changes in operating

parameters or design Involves: PVT Wellbore IPR Nodal Analysis


13/48

Well Modelling Fundamentals

Nodal Analysis It is the methodology used in well modelling to analyse theperformance of a multi-component system

Objectives are to: Quantify total pressure loss as a function of rate

Quantify components within total pressure loss Identify bottlenecks to flow Optimise system design and operation given constraintAddress specific well issues such as Artificial lift, well load up,completion design optimisation and productivity improvementopportunities.

Important:Nodal analysis assumes a steady state anddoesnot allow transient flow behaviour.


14/48


Common Nodes used in Nodal Analysis


15/48


16/48


Top Node Bottom Node Solution Node Comments

Wellhead Reservoir Mid-perf Separates IPR from VLP

Wellhead Reservoir ESP, GL, et !o esta"lish artifial lift re#irements

W$ %ho&e Gauge 'epth Wellhead !o math given test dataSeparator Reservoir Wellhead Separates (ell-reservoir from surfae

Separator Reservoir %ho&e %om"ines ho&e effet (ith (ell-reservoir

Separator Wellhead Manifold%onentrating on )et(or& modelling (ith

&no(n ontri"ution from (ell*s+


17/48

CONTENTSIntroductionWell Modelling FundamentalsSetting up a well modelPVT modellingIPR modellingVLP modellingVLP / IPR matching and model validationConclusions


18/48

SETTING UP A WELL MODEL

What information do you need? Completion diagram / tally and directional surveydata, together with any recent work-over info/data

Fluid data (PVT reports or existing PVT model) Complete production test data (recent as wellhistorical sets) comprising of rates, phase ratios, endpressures, etc.

Reservoir and available near-wellbore data (reservoirpressure & temperature, FBHP/downhole gage

pressure, PI, skin, permeability and rel perm, etc).


19/48


Surface choke

Sales LineGas

Separator

LiquidStock

Tank

To Sales

Bottom hole

restriction

PsepP5 = (Pwh - PDS!

PDS

P6 = (PDSC - Psep)

P" = (Pwh - Psep!

Pwh

PDSV

PUSV

PDR

PUR

Pwf Pwfs Pr Pe

P# =

(P$%- PD%!

P& = (Pwf- Pwh!

P' = (P$S - PDS!

P) = (Pwfs - Pwf! P* = (Pr - Pwfs!

P+ = (Pr - Pwf!

P" = Pwh - Psep

P, = PDS - Psep

P5 = Pwh - PDS

P' = P$S - PDS

P& = Pwf- Pwh

P# = P$%- PD%

P) = Pwfs - Pwf

P+ = Pr - Pwf

P* = Pr - Pwfs = Loss in porous medium

= Loss across completion

= Loss across restriction

= Loss across safet .al.e

= Loss across surface choke

= Loss in flowline

= Total loss in tu/in0

= Total loss in flowline= Total loss in reser.oir 1 completion

Surface choke

Sales LineGas

Separator

LiquidStock

Tank

To Sales

Bottom hole

restriction

PsepP5 = (Pwh - PDS!

PDS

P6 = (PDSC - Psep)

P" = (Pwh - Psep!

Pwh

PDSV

PUSV

PDR

PUR

Pwf Pwfs Pr Pe

P# =

(P$%- PD%!

P& = (Pwf- Pwh!

P' = (P$S - PDS!

P) = (Pwfs - Pwf! P* = (Pr - Pwfs!

P+ = (Pr - Pwf!

P" = Pwh - Psep

P, = PDS - Psep

P5 = Pwh - PDS

P' = P$S - PDS

P& = Pwf- Pwh

P# = P$%- PD%

P) = Pwfs - Pwf

P+ = Pr - Pwf






= Loss in flowline



P" = Pwh - Psep

P, = PDS - Psep

P5 = Pwh - PDS

P' = P$S - PDS

P& = Pwf- Pwh

P# = P$%- PD%

P) = Pwfs - Pwf

P+ = Pr - PwfP+ = Pr - Pwf






= Loss in flowline



Sources of pressure loss in a production system


20/48


Pre-processing data Completion data consistent with directional survey

and other work-over info.

Fluid data/PVT model consistent with other wells andformation info.

Production test data complete and consistent with

current well performance.

Reservoir data dates consistent with the production

test dates.


21/48

SETTING UP A WELL MODELSystem Summary Screen

Can model upto5 stages forcompmodelling

Select1. tubing or2. annular or3. tubing ANDannular

Informationonl

!sefulrepositorfor "ell testand modelinformation

#eser$oirconnectionoptions %

in&uence laterin&o" options

Specif "'et'era single "ell or

multilateral

Specif tpe oftemperaturemodelling

De(ne &uid tpe and P)*

met'od +i.e. blac, oil ore-uation of state model


22/48

PVT Property

(Pb) Bubble-point

Pressure (psia)

(Bo) Bubble-Point

il !V! (rb"stb)

(#R or Rs) #as"il

Ratio (s$f"stb)

Reser%oir

Temperature (&!)

Sto$' Tan' il

#ra%ity (&P)

#as Spe$ifi$ #ra%ity

(air * +)

Separator Pressure

(psia)

Separator

Temperature (&!)

PVT Property

(Pb) Bubble-point

Pressure (psia)

(Bo) Bubble-Point

il !V! (rb"stb)

(#R or Rs) #as"il

Ratio (s$f"stb)

Reser%oir

Temperature (&!)

Sto$' Tan' il

#ra%ity (&P)

#as Spe$ifi$ #ra%ity

(air * +)

Separator Pressure

(psia)

Separator

Temperature (&!)

Standin,

+. / 0...

+1.23 / 21+4

2. / +324

+.. / 245

+614 / 615

.147 / .174

264 / 364

+..

Standin,

+. / 0...

+1.23 / 21+4

2. / +324

+.. / 245

+614 / 615

.147 / .174

264 / 364

+..

8asater

35 / 405.

N"

/ 27.4

52 / 202

+017 / 4+1+

.1403 / +122

+4 / 6.4

6 - +.6

8asater

35 / 405.

N"

/ 27.4

52 / 202

+017 / 4+1+

.1403 / +122

+4 / 6.4

6 - +.6

Va9:ue9-

Be,,s

+4 / 6.44

+1.25 / 21226

.1. / 2+77

04 / 273

+41 / 4714

.14++ / +14+

6. / 464

06 / +4.

Va9:ue9-

Be,,s

+4 / 6.44

+1.25 / 21226

.1. / 2+77

04 / 273

+41 / 4714

.14++ / +14+

6. / 464

06 / +4.

#las;

+64 / 0+32

+1.50 / 21455

7. / 260

5. / 25.

221 / 351+

.164 / +1206

3+4

+24

#las;

+64 / 0+32

+1.50 / 21455

7. / 260

5. / 25.

221 / 351+

.164 / +1206

3+4

+24

Petros'y-

!ars


23/48

CONTENTSIntroductionPVT Fundamentals

Well Modelling FundamentalsSetting up a well modelPVT ModellingIPR modelling

VLP modellingVLP / IPR matching and model validationConclusions


24/48


PVT Model Tuning

Select PVT correlations relevant to the given fluids.

If PVT matching data absent or sparse use

correlation which has proved appropriate in offsetwells / fields

Use corrected PVT data to tune the selected PVT

correlations


25/48

SETTING UP A WELL MODELPVT Summary

PVT modelling involves:

Gathering quality test data

Convert Diff Lib data to flash conditions if required (correction)

Selecting appropriate correlation/EoS.

Tuning selected correlation/EoS.

Generating PVT properties at all pressure-temperature combinations

encountered in flow stream.

There is no substitute for quality test data.

Incorrect PVT model has detrimental effect on IAM modelling, which is

quite often incorrectly accounted for by adjusting flow correlations.

Note that in gas condensate wells, inaccurate temperature

modelling can have a profound effect on PVT often neglected

S tti ll d l


26/48

STEP 1: BASIC PVT DATA

INPUT Basic Data Input from PVT report, DST testing(may sometimes be all that is available)

Setting up a well model


27/48


Match Data input from PVT report use onlyflash correcteddata. Normally enter as much data as possible to optimisecorrelation matching

Step 2: PVT Match Data Input

S i ll d l


28/48

STEP 3: MATCHING PVT CORRELATIONS TO REAL

PVT DATA PVT correlations are empirically derived mathematical fits of real experimental data Correlations approximate real fluid behaviour some more suitable than other for certainfluid systems

Matching is a regression process which reduces the error between correlation and PVT data

User can specify which gas properties it is critical to match (to reflect possible uncertainty ininput data accuracy

Parameter 1 and 2 statistics provide match quality and correlation predictive reliability Parameter 1 is the multiplier which has to be applied to correlation (should be within 10% of unity) Parameter 2 is the shift

Setting up a well model


29/48

SETTING UP A WELL MODELEntering a physical description of the well and its

subsurface environment

Enter up to 18 depth pairs (measured & TVD)

Include effect of any pipework from wellhead to manifold(incl choke)

ID / OD and roughness of all tubing and casing, restrictions

etc down to the reservoir. Mid-perf depth is bottom depth

entered.

Input formation temperatures versus depth, and overall

Heat Transfer coefficient (U value)

Enter specific heats for oil, water and gas use default

Values In this example


30/48


Only enter minimum number

of points required to describe

basic shape of wellpath

Tip: normally use survey

points giving >5% change ininclination

EnteringDeviation SurveyData


31/48


Manifold (or other constant

pressurenode in system)

Surface equipment

NB:

Enter UPSTREAM endTVDs for each section of pipe

(i.e. nearest the tree for

producers)

Use Plot to visualise

pipework layout and checkfor errors

Can use an X-Y

coordinate system if required

to enter more detailed

pipework desciption

(applicable to subsea)

Entering theSurface Equipment Description


32/48


Notes:

Typically use drilling depth references i.e. relative to rotary table - e.g. in a subsea well Xmas tree

depth may be +400 ft Enterbottomdepth of each section of same diameter tubing, associated ID and roughness Enter SSSVs and restrictions

Casing depth where you wish pressure loss calculations to begin (typically mid perf).

In a long perforated interval may be better to use more complex inflow model

Downhole Equipment Description

#oug'ness/uidelines

Plastic .! in"r Steel .# inSS .# in" Steel New .$% in to Old .# in


33/48


Notes:

Enter a temperatures survey obtained from STATIC logging, or best offset

data

Ensure a survey point for the bottom node in the equipment data is included.

Geothermal Gradient calculations enable Prosper to predict flowing wellbore temperaturesfrom reservoir to wellhead under various scenarios, based upon anOverall Heat Transfer

Coefficient orUvalue.

Typical Values are: Oil wells 8 BTU/h/ft2/F

Gas wells 3 BTU/h/ft2/F

Gas Cond wells 3.7 BTU/h/ft2/F

Geothermal Gradient


34/48

CONTENTSIntroductionPVT Fundamentals

Well Modelling FundamentalsSetting up a well modelIPR modellingVLP modelling

VLP / IPR matching and model validationConclusions


35/48

IPR MODELLINGFundamental Input information:Reservoir Pressure & temperatureAt least one stable flowing BHP and rate (ensurereservoir pressure consistent in time with FBHP ifvarying)

GOR (oil well) / CGR (gas well)Watercut (oil well) / WGR (gas well)

Theoretical vs empirical IPR modelsReservoir / Completion parameters:Rock permeability & anisotropyProducing interval, perforations, deviation & drainagearea

Gravel Pack properties & dimensions


36/48

IPR MODELLING

The Inflow Performance Relationship (IPR) defines the pressuredrawdownin a well as afunction of production rate

Drawdown is a complex function of PVT, permeability (absolute & relative), effective overburder

etc

Several IPR model available optimum choice depends on data available and calculations

required including:-

Gas Well PI Models

Jones~ includes a linear (Darcy) pressure drop and a rate-squared (non-Darcy) term.

Uses pseudopressure, better for high reservoir pressures (>2000 psi)

Backpressure,

Forcheimer,

C and N~ use various backpressure equations to describe the Darcy and non-Darcy

inflow behaviour

Petroleum Experts ~uses a multi-phase pseudo pressure function to allow for changing

gas and condensate saturations with pressure applicable to gas condensate modelling or

dry gas

IP& Fundamentals


37/48

IPR MODELLING

Oil Well PI Models

PI entry~ simplest, useful where no where no reservoir perm

or skin data available, and where the PI is already known

Vogel~ uses an empirical correlation to account for deviation

from straight line PI below bubble point

Composite~ interpolates a Vogel IPR for oil and straight line

IPR for oil as a function of watercut useful for sensitivities on

increasing watercut

Darcy~ classic radial flow equation useful for estimating

productivity from petrophysical data

Fetkovich~ adapted from isochronal theory gives similar

results to Vogel


38/48

IPRMODELLING

Options will

dependon fluid type

selected

in SystemSummary

S'in modelde(nition

Select the Jones model (modified form of Darcy Equation)

Defining IPR model to be used:


39/48

IPR MODELLING

)nter data in all s*eets wit* *ig*lig*ted ta+s ,wor'ing left to rig*t-

Entering IPR data


40/48

IPR MODELLING

W*en data entr complete/ clic' on 0"alculate1 +utton to generate IP& plot

Entering IPR data


41/48

IPR MODELLING

2OF3 2+solute Open 4ole Flow Potential,t*eoretical 5ow potential assuming 6ero7ac'pressure-

Static reser8oir pressure

Flowing +ottom *ole pressure ,F74P-

IPR curve gas well


42/48

CONTENTSIntroductionPVT FundamentalsWell Modelling Fundamentals

Setting up a well modelIPR modellingVLP modellingVLP / IPR matching and model validationConclusions


43/48

VLP MODELLING!low Patterns"Re,imes in Verti$al Upward !low

BUBB8>

!8?

SL$G

2L34

$%6

2L34

766$L7%

2L34

BUBB8>

!8?

SL$G

2L34

$%6

2L34

766$L7%

2L34

"O99ON FLOW &):I9) IN

:2S ; :2S "ONLP 9odelling


44/48

ROLE OF MULTI-PHASE FLOW CORRELATIONS

=>LP correlations predict t*e pressure loss in pipe/allowing for t*e gra8it/ friction and acceleration e?ects

= "orrelations *andle Slip/ *oldup and multip*ase 5owpattern in di?erent was e.g. slip/ 5ow regime accountedfor ; not accounted for

="orrelations using 5ow maps ma gi8e discontinuousresults @ modern mec*anistic correlations o8ercome t*is.

=No single correlation is 0+est1/ and comparison of t*ecorrelations is recommended to select t*e t*e optimumone for a gi8en application

>LP 9odelling


45/48

VLP

MODELLING(utear Data Sour$e Nominal )D !luids @ Rates Comment

Duns @ Ros ri,inal . /01 high e2perimental loop3field

data

45.6 to 04.6 (ith

5 annulus onfig4

7ir, (ater 8 li#uid

h9droar"on

Good over a (ide range, more so for mist

flo(s, tend to overpredit VLP in oil (ells

Duns @ Ros =odified

!ran$d 8 G?R

@0===

Aeing no-slip al(a9s predits lo(est pressure

drops therefore good for data B%

Aa,edorn @ Brown .0 MM (ith veloities

up to 0=ft>s

E2ellent for gas and gas-ondensate (ells

"ut should "e used (ith aution for higher

WGR>%GR

Multiphase Flow Correlations available inProsper

"orrelations suita+le for gas wells

CONTENTS


46/48

CONTENTS

IntroductionPVT FundamentalsWell Modelling FundamentalsSetting up a well model

IPR modellingVLP modellingVLP / IPR matching and model validationConclusions

CONTENTS


47/48

CONTENTS

IntroductionPVT FundamentalsWell Modelling FundamentalsSetting up a well model

IPR modellingVLP modellingVLP / IPR matching and model validationConclusions


48/48

THANK YOU

production petroleum software (1)

Documents