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MSc (Petroleum Engineering)Project Report 2012/2013
Obinna NwaforH00137989
History Matching and Uncertainty
Quantification with Produced Water
Chemistry
Heriot-Watt UniversityInstitute of Petroleum Engineering
Supervisor-
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Declaration:
IObinna Nwaforonfim tht thi wok bmittd fo mnt i
my own and is expressed in my own words. Any uses made within it of theworks of other authors in any form (e.g. ideas, equations, figures, text,tables, programs) are properly acknowledged at the point of their use. Alist of the references employed is included.
Signd..
Dt20August, 2013
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Acknowledgements
I would like expressly my profound gratitude to my Supervisor Oscar Vasquez for his tireless effortin guiding me through this work. He has taken me from reservoir studies, and mixed in a little bit ofchemistry and lots mathematics. Without his kind reassurance, I would not have come this far.
My gratitude also go to th whol Untinty research group at IPE, Heriot-Watt University, ledby Mike Christie. I am very grateful to Mike, especially for those solutions he throws my way at themoments my wits were fully spent. Vasily Demyanova has been to me a great teacher and guide,especially with the woolly concepts of uncertainty quantification. He never once got deterred by mysilly questions, which popped out every morning. I am truly thankful. Dan Arnolds has beeninvlbl to m in thing ndtnding tht n wy. He takes time to lead them back-in,ensuring they were securely tucked into their beds.
I would not have had the courag to tk on mthmtil optimition withot thencouragement from Eric Mackay. I am truly thankful to his insight, especially those words aboutft job pnttion. My gtitd lo go to th Chplin of Hiot -Watt University,Alastair Donald, every Sunday I found my way back to him for the spiritual fodder that kept megoing.
I appreciate Epistemy Ltd for the Raven software used for this study, and the Computer Support
Team who kept the systems running in spite of the mounting pressure.
I wish to acknowledge all my lectures and tutors at the IPE over the last one year, they gave me a
little bit of themselves, which I have put together in this work.
My parents, especially mother, my sisters and brother in-law have been a rock to me throughoutmy one year stay in Edinburgh which culminated in this work. Thank you for being there, caring
and offering your words and resources. I thank the Almighty God for his grace every step of the
way.
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Abstract
History matching is used in reservoir calibration. Conventional history matching could be improvedby addition of more constraints to be matched. The injected sea water, produced as part of associated
water could have the potential of serving as an additional constraint. Such data can be obtainedcheaply by using ion in sea water as natural tracers.
This study aims to determine the extent of improvement to history matching and reduction ofuncertainty in forecasts brought about by the addition of injected sea water production data to thehistory matching process. The study was carried out using the PUNQS3 reservoir model. It is asynthetic reservoir model that has been used for similar studies and severally to test out methods inhistory matching and uncertainty quantification. The uncertain parameters in the PUNQS3 model arethe porosity and permeability.
Two cases of automatic history matching were carried out. One involved the use of injected sea
water tracer production data as additional constraint. The other involved using only the conventionalproduction data. The automatic history matching was based on multi-objective particle swarmoptimization (PSO). Which is a nature inspired stochastic optimization technique. The uncertaintyquantification was done using Neighbourhood Approximation method (NA-Bayes) based on aBayesian framework. The result for the two cases was compared on the basis of advance of theirpareto front of models ensemble towards lower misfit values. The quality of history matching andsize of uncertainty were also considered. They all show indications that addition of injected sea waterproduction data improves the history matching process, reduced uncertainty in forecast, as well ascreates a more robust uncertainty quantification. However the improvements were not large, butcould be more significant for more complex reservoir history matching problems.
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Table of ContentsAcknowledgements ......................................................................................................................... ii
Abstract ........................................................................................................................................... iii
1 Aims......................................................................................................................................... 12 Introduction ............................................................................................................................. 2
2.1 Reservoir History Hatching .............................................................................................. 2
2.2 Automatic History Matching and Mathematical Optimization ........................................ 3
2.2.1 Construction of Inverse Problems and Mathematical Optimization Problems ......... 4
2.3 Value of improved history matching ................................................................................ 4
2.4 Tracing Injected Sea Water in Hydrocarbon .................................................................... 5
2.4.1 Origin of Oilfield Water ............................................................................................ 5
2.4.2
Composition of Oil Field Water ................................................................................ 6
2.4.3 Compatibility of Formation Water and Sea Water .................................................... 6
3 Review of Concepts and Studies ............................................................................................. 9
3.1 Stochastic Optimization Techniques for History Matching.............................................. 9
3.1.1 Genetic Algorithm ................................................................................................... 10
3.1.2 Differential Evolution .............................................................................................. 10
3.1.3 Ant Colony Optimisation......................................................................................... 11
3.1.4 Particle Swarm Optimisation ................................................................................... 12
3.1.5 Use of Particle Swarm Optimization for Reservoir History Matching OptimizationProblem 14
3.1.6 Multi-Objective Particle Swarm Optimization. ....................................................... 14
3.1.7 Optimal Solutions in Multi-Objective Optimization: Pareto Front ......................... 15
3.2 Uncertainty Quantification for Forecast ......................................................................... 16
3.2.1 Definition of Uncertainty ......................................................................................... 16
3.3 Uncertainty Quantification Method: Neighbourhood Approximation Using BayesTheorem (NA-Bayes) ................................................................................................................ 17
3.3.1 Bayes Theorem ........................................................................................................ 18
3.3.2 Likelihood of Observation ....................................................................................... 193.3.3 Bayes Integral: Resampling by NA-Bayes .............................................................. 20
3.3.4 Neighbourhood Approximation and MCMC Walk ................................................. 20
3.3.5 Bayesian Credible Intervals ..................................................................................... 22
3.4 Review of Empirical Studies on Improving History Matching by Adding Data onInjected Sea Water Production .................................................................................................. 22
3.5 Problem Statement .......................................................................................................... 24
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4 Data Summary: PUNQS3 Reservoir Model .......................................................................... 27
4.1 Origin .............................................................................................................................. 27
4.2 Available Reservoir Description ..................................................................................... 27
5 Methods ................................................................................................................................. 295.1 Work Flow Diagram ....................................................................................................... 29
5.2 PUNQS3 Problem: Uncertain Parameters ...................................................................... 30
5.3 Modifications to the PUNQS3 and Historical Data ........................................................ 30
5.4 Parameterisation .............................................................................................................. 30
5.4.1 Regions and Justification/ Generation of Simulation Files ..................................... 31
5.4.2 Correlation of Porosity and Permeability ................................................................ 33
5.4.3 Parameter Distribution ............................................................................................. 34
5.5 Selection of Histories to Match and Objective Functions for Optimisation ................... 34
5.5.1 Case 1: ..................................................................................................................... 35
5.5.2 Case 2: ..................................................................................................................... 37
5.6 Generation of Truth Case Histories ................................................................................ 37
5.7 Variance for History Data ............................................................................................... 38
5.8 Optimisation Algorithm and Setup ................................................................................. 39
5.8.1 Setup of PSO run ..................................................................................................... 40
5.8.2 Ensemble of Models: convergence of ensemble; number of Ensembles ................ 41
5.9 Uncertainty Quantification: ............................................................................................ 41
5.9.1 Prior Probabilities .......................................................................................... 425.9.2 Likelihood of Models ................................................................................ 425.9.3 Monte Carlos Integration of the Bayesian Integral ................................................. 43
5.9.4 Bayesian Credible intervals. .................................................................................... 44
5.10 Analysis of Results ...................................................................................................... 44
5.10.1 Research Question 1 ................................................................................................ 44
5.10.2 Research Question 2 ................................................................................................ 44
5.10.3 Research Question 3 ................................................................................................ 45
6 Results ................................................................................................................................... 46
6.1 Research Question 1 ....................................................................................................... 46
6.1.1 Identification of Pareto Solutions Models for Case 1 and Case 2 ........................... 46
6.2 Research Question 2 ....................................................................................................... 47
6.3 Research Question 3 ....................................................................................................... 49
7 Discussion and Conclusion .................................................................................................... 50
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7.1 Improvement to History Matching.................................................................................. 50
7.2 Economic Value .............................................................................................................. 52
7.3 Reduction of Uncertainty ................................................................................................ 52
7.4 Conclusion ...................................................................................................................... 538 References ............................................................................................................................. 55
9 Appendix ............................................................................................................................... 58
9.1 Detailed Comparison of Front Advance by Region ........................................................ 58
9.1.1 Case 1: Excluding Sea Water Tracer Production Data ............................................ 59
9.1.2 Case 2: Excluding Sea Water Tracer Production Data ............................................ 60
9.2 3 Dimensional Pareto Plot for Case 1 ............................................................................. 60
9.3 Field Oil Production Total (FOPT) Intervals for Case1, C-Case and Case 2 ................. 61
9.4 Comparison of History Match for Best Five Models of Case 1 and Case 2 ................... 64
Well Water Production Rate ...................................................................................................... 64
9.5 Well Bottom Hole Pressure ............................................................................................ 67
9.6 Comparison of History Match for Most Pareto Models for Case 1(Iteration 493 Run2)Case 2(Iteration 262 Run3)-Well Bottom Hole Pressure .......................................................... 70
9.7 Comparison of History Match for Most Pareto Models for Case 1(Iteration 493 Run2)Case 2(Iteration 262 Run3) - Well Water Production Rate ....................................................... 73
9.8 Field Oil Production Total .............................................................................................. 76
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Table of FigureFIGURE 3-1VORONOI CELLS FOR TEN RANDOM POINTS (MODELS) IS A SOLUTION SPACE. B. THE UPDATED
VORONOI CELLS AFTER 100 POINTS ARE SAMPLED AND INTERPOLATED USING GIBBS SAMPLER. .................. 21
FIGURE 4-1 EXPECTED FACIES WITH ESTIMATES FOR WIDTH AND SPACING OF MAJOR FLOW UNITS ...................... 28
FIGURE 5-1WORK FLOW DIAGRAM ............................................................................................................................. 29
FIGURE 5-2 INJECTORS AND PRODUCER WELLS ON THE PUNQS3 RESERVOIR MODEL .............................................. 30
FIGURE 5-3SAMPLE OPTIMIZATION RESULT-QUALITATIVE PERMEABILITY MAP-LIGHT BLUE SHOWS HIGHER PERM.
........................................................................................................................................................................... 32
FIGURE 5-4 3 LAYER 3 PARAMETERISATION ................................................................................................................ 32
FIGURE 5-5 LAYER 2 PARAMETERISATION .................................................................................................................. 32
FIGURE 5-6 LAYER 1 PARAMETERISATION ................................................................................................................... 32
FIGURE 5-7 LAYER 5 PARAMETERISATION ................................................................................................................... 32
FIGURE 5-8 LAYER4 PARAMETERISATION.................................................................................................................... 32
FIGURE 6-1 CASE 1: SWTP PARETO PLOT .................................................................................................................... 46
FIGURE 6-2 CASE 2: NSWTP PARETO PLOT .................................................................................................................. 46
FIGURE 6-3 COMPARISON OF PARETO BY TRADE-OFF REGIONS ................................................................................ 47
FIGURE 6-4 CASE2: NSWTP FOPT ................................................................................................................................ 48FIGURE 6-5 CASE1: SWTP FOPT ................................................................................................................................... 48
FIGURE 6-6 CASE 2: NSWTP-FWPT .............................................................................................................................. 49
FIGURE 6-7 CASE 1: SWTP-FWPT ................................................................................................................................. 49
FIGURE 6-8 TERMINAL FWPT UNCERTAINTY LESS FOR CASE 2 ................................................................................... 50
FIGURE 6-9 TERMINAL FOPT UNCERTAINTY LESS FOR CASE 1 .................................................................................... 50
FIGURE 9-1 CASE 1: SWTP PARETO PLOT IN REGIONS ................................................................................................ 59
FIGURE 9-2 CASE 2: NSWTP PARETO PLOT IN REGIONS .............................................................................................. 60
FIGURE 9-3 3D PARETO PLOT CASE 1: INCLUDE SEA WATER TRACER PRODUCTION DATA ........................................ 60
FIGURE 9-4 CONTROL CASE -C FOPT-SWTP SHOWS SAME TREND AS CASE 1: SWTP ................................................. 61
FIGURE 9-5 CASE 1: SWTP FOPT FULL PLOT ................................................................................................................ 62
FIGURE 9-6 CASE 1: SWTP FOPT FULL PLOT ................................................................................................................ 62
FIGURE 9-7 WWPR PRO-1-BEST FIVE MODELS OF EACH CASE .................................................................................... 64
9-8 WWPR PRO-4 BEST FIVE MODELS OF EACH CASE ................................................................................................. 64
9-9 WWPR PRO-5-BEST FIVE MODELS OF EACH CASE................................................................................................. 65
9-10 WWPR PRO-11-BEST FIVE MODELS OF EACH CASE............................................................................................. 65
9-11 WWPR PRO-12-BEST FIVE MODELS OF EACH CASE............................................................................................. 66
9-12 WWPR PRO-15-BEST FIVE MODELS OF EACH CASE............................................................................................. 66
9-13 WBHP PRO-1-BEST FIVE MODELS OF EACH CASE ................................................................................................ 67
9-14WBHP PRO-4-BEST FIVE MODELS OF EACH CASE ................................................................................................ 67
9-15 WBHP PRO-5-BEST FIVE MODELS OF EACH CASE ................................................................................................ 68
9-16 WBHP PRO-11-BEST FIVE MODELS OF EACH CASE .............................................................................................. 68
9-17 WBHP PRO-12-BEST FIVE MODELS OF EACH CASE .............................................................................................. 69
9-18 WBHP PRO-15-BEST FIVE MODELS OF EACH CASE .............................................................................................. 69
9-19 WBHP PRO-1 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS .................................................................... 70
9-20 WBHP PRO-5 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................... 709-21 WBHP PRO-4 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................... 71
9-22 WBHP PRO-11 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................. 71
9-23 WBHP PRO-12 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................. 72
9-24 WBHP PRO-15 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................. 72
9-25 WWPR PRO-1 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS .................................................................. 73
9-26 WWPR PRO-5 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................... 73
9-27WWPR PRO-5 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS .................................................................... 74
9-28 WWPR PRO-11 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................. 74
9-29 WWPR PRO-12 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................. 75
9-30 WWPR PRO-15 CASE1 VS. CASE2 MOST PARETO OPTIMAL MODELS ................................................................. 75
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9-31 FIELD OIL PRODUCTION TOTAL ........................................................................................................................... 76
TablesTABLE 5-1 LIST OF PARAMETER FOR PUNQS3 RESERVOIR .......................................................................................... 33
TABLE 5-2 DISTRIBUTION OF PARAMETER .................................................................................................................. 34
TABLE 6-1 MISFIT OF FIELD OIL PRODUCTION TOTAL FOPT FROM TRUTH CASE ........................................................ 47
TABLE 6-2 MISFIT OF FIELD WATER PRODUCTION TOTAL FWPT FROM TRUTH CASE ................................................ 47
TABLE 6-3 MISFIT FOPT FROM P(50) AS A MEASURE OF SPAN OF UNCERTAINTY ENVELOPE .................................... 48
TABLE 6-4 MISFIT FWPT FROM P(50) AS A MEASURE OF SPAN OF UNCERTAINTY ENVELOPE ................................... 48
TABLE 9-1 COMPARISON OF FRONT ADVANCE BY REGION ........................................................................................ 58
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1 AimsAutomatic history matching involves the use of mathematic optimization algorithms to determine
perform reservoir model calibration. However useful, it never yields unique single answers nor
eliminate totally the uncertainties associated with the reservoir model. The value of a well
calibrated reservoir model is the reduction in uncertainty or increase in reliability of the
performance data it provides to the decision process, involving the huge financial resources
invested to exploit hydrocarbon reservoirs. Hence, this study is a quest for improvement to the
history matching process.
It has been proposed by several previous studies that since injected sea water carried
complementary information on flow paths within the offshore reservoirs, its use as an additional
constraint in history matching could greatly improve the process, yielding highly reliable models
and reducing uncertainty in forecasts. In this view, the specific objectives of this study are:
To carry out a comparative history match of a synthetic reservoir model in two cases, one
constrained additionally by production data of injected sea water.
To effect the generation of sea water production data using the equivalent of natural water
tracers in the reservoir model.
To establish using an appropriate measure, if the addition of injected sea water production
data in one case has impacted in it, a better performance of the history matching process.
To establish using an appropriate measure, if the addition of injected sea water production
data in one case has impacted in it, a reduction in the size of uncertainty associated with
the forecasted performance of the reservoir.
To make conclusions on the potential of injected sea water production data in improving
reservoir history match results
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2 Introduction
2.1 Reservoir History HatchingIt is common to use numerical simulators to predict the performance of a reservoir. The
reliability of a reservoir simulation result is dependent on the inputs to the reservoir model
description. This input can be classified as relating to static (geological) properties description, or
dynamic (fluid flow) properties. Such information is gathered in the course of exploration and
appraisal. Static data will include time independent information derived from cores, wire line
logs, seismic surveys, etc. Dynamic data are time dependent data derived from flow relations,
they relate to reservoir properties such as relative permeability, fluid saturations, viscosity, flow
rate, fractional flows, etc. (Cheng et al., 2004, p.1). It is impossible to eliminate all uncertainties
in a reservoir.
History Matching is a major technique for calibrating the reservoir model in order to
maximize reliability of simulation results. It is the fine tuning of estimated reservoir description
parameters to match known past performance of the reservoir such as fluid rates, well bottom-
hole pressures, field average pressures, etc. History matching is an inverse problem, we attempt
to use the observed data about a reservoir to predict its properties. As is typical of inverse
mathematical problem, the solutions are never unique (Cunha, Prais, & Rodrigues, 2002, p.1).
Conventional history matching involves manual variation of field description parameters.
Simulation runs a made for each variation of model parameters, and the simulation results are
compared with the historical values. This is expensive in terms of human labour and computing
time. It is also highly subjective as the iteration direction depends on experience and insight.
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2.2 Automatic History Matching and Mathematical Optimization
Several History matching techniques have been studied and applied in the quest to
automate the process of finding solutions to history matching problems. They take the approach
of treating the inverse problem as a mathematical optimisation problem, in which a defined
objective function is either maximized or minimized. This objective function takes the form of a
function of the difference between observed history data and simulated result data (Cunha et al.,
2002).
Cunha et al. (2002, p.2) also indicates that automatic history matching can be broadly
classified into two groups, gradient based techniques and stochastic techniques. (Sarma,
Durlofsky, Aziz, & Chen, 2007, p.1) identified the streamline based history matching technique
as a class of its own. Each method has its own limitations and strengths.
The deterministic or gradient based techniques uses gradients of the mathematical model,
related to the parameterised properties of the model, to minimize the objective function which is
based on misfits between historical data and simulated results (Cunha et al., 2002, p.2). They are
known to converge very fast. However, they are poorly adapted to the multi-modal and non-
unique nature of solutions to history matching problems. Sarma et al.(2007) and Cunha et
al.(2002) agree that gradient based minimization is easily trapped into local minima point.
Stochastic history matching techniques have the exact opposite properties to gradient
techniques. They require a large number of simulation, hence, convergence and computing time
is quite significant. However, they are not easily trapped in local minima point, rather they effect
a more efficient search of the solution space. Sarma et al. (2007, p.1) noted that stochastic
techniques more easily honour complex geological models as they treat the simulator as a black
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box. The Streamlined based history matching techniques are limited by their inability to model
complex physics.
2.2.1
Construction of Inverse Problems and Mathematical Optimization Problems
As has been discussed earlier, history matching an inversion process where historical
production data of a reservoir is used to improve the estimates of parameters which characterize
the reservoir. Sarma et al.(2007, p.3) expressed the general construction of history matching
problem as mathematical optimization as follows:
( )
EQ. 2-1Where
Y refers to model parameter to be estimated; Yprior refers to the initial parameter estimates
C refer to the covariance which with Yprioris determined from the initial geological model
X refers to the states of the reservoir at various time N in Simulations. Such that f
n(X
n+1,
Y) simply refers to production data.
gn (Xn+1, Xn, Yn) represents the equations to which the simulator constrains the
reservoir model, linking the Parameters Y and reservoir states or results X.
The Lagrangian Ln
(Xn, Y
n) is the estimate of error between the observed data Dobs and the
simulated result fn(X
n+1, Y) also referred to as Misfit M.
is the variance of the data2.3 Value of improved history matchingHistory matching is applied to calibrate a reservoir model. Calibration has the singular
purpose of ensuring that simulations results are very reliable. Simulations results are applied to
Subject to the conditions:
Initial Conditions expressed as values X0
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field development planning, field optimization, economic evaluation of fields, testing of solution
ideas for field exploitation. These activities all have an economic value in the chain relevant to
production of the hydrocarbon.
It is impossible to accurately model every aspect of a real reservoir, hence every
simulation results has an attached uncertainty. Where history matching has been effectively
applied to a reservoir model, the uncertainty in the simulation results can be significantly
reduced. Statistical techniques can be used to quantify uncertainty.
The economic value of reservoir history matching lies in the reduction of uncertainty.
Uncertainty reduction facilitates the decision making process and risk management. The value of
improved history matching will stem from having results with fewer solution models and a direct
reduction in the uncertainty. The economic value of history matching will vary for each reservoir.
It is possible to quantify this economic value if we can quantify the reduction in uncertainty of
economic parameters resulting from the application.
2.4 Tracing Injected Sea Water in Hydrocarbon
2.4.1 Origin of Oilfield Water
The US Geological survey indicates that ground water constitute only about 1.7% of the
all the water on earth (U.S. Geological Survey, n.d.). Ground water in oil fields come from
various sources (Collins, 1975, p.194) classified as follows:
Meteoric Water: - Water tht h ntly bn in tmophi iltion
Sea Water: - This refers to water from modern sea, used for water flooding.
Interstitial Water:- Water occupying the pore spaces in formation rock (aquifer water).
Connate Water: - Refers to interstitial water of syngeneic origin with the formation rock..
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Digenetic Water: -Water with chemical or physical change from rock sedimentation.
The injected sea water applies for offshore field, where sea water being the most available water
source, is used for water flooding. Produced water from an oil reservoir, for the purpose of this
study will be grouped into two, namely: Injected Sea Water and Formation Water. The formation
water is made up of connate water, aquifer or interstitial water and digenetic water.
2.4.2 Composition of Oil Field Water
The water in modern sea is generally saline. The salt or ion composition is mainly of
hloid (Cl), odim (N+), sulphate (SO24), mgnim (Mg2+), calcium (Ca2+), and
potassium (K+). They constitute about 90 percent of all the salt in sea water. While inorganic
carbon, bromide, boron, strontium, and fluoride constitute the other major dissolved content of
seawater. MacKenzie (2013) gives a full list sea water composition.
Formation water cannot be ascribed a single composition as they come from various
sources and pass through various physical and chemical processes. In a study of water from
various geological aged rocks, Collins, (1975, p.216) concluded that the water were not of the
same chemical composition, and have evolved considerably compared to the modern sea water.
Any water in the reservoir can be modified by four major processes, dilution by meteoric
water or fresh water, reaction with minerals in the rock formation, clay membrane filtration and
ion exchange, mixing of sea water and aquifer water resulting in precipitations.
2.4.3 Compatibility of Formation Water and Sea Water
Vazquez, McCartney, et al.(2013,p.1) observed that injected sea water and formation
water
can be quite incompatible for mixing. Mixing of both waters could result in several possible
geochemical reactions which may lead to scale precipitation. Precipitation of insoluble
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compounds result in formation damage through reduction of permeability and porosity of the
reservoir. Collins (1975, p.367) identified the ions responsible for formation of scale from water
mixing as Ca
+2
,Sr
+2
, Ba
+2
, Fe
+2
, SO4-2
, HCO3-
. The time and actual precipitation of the scale may
be subject to other environmental changes such as pressure and temperature changes or factors
that affect concentration of the brines. The most notorious of the scales is barium sulphate
BaSO4which is highly insoluble and often impossible to remove once formed.
2.4.3.1 Conservation of Natural Tracers within Reservoir
Valestrand et al.(2008, p.2) defined tracers as inert chemical or radioactive compounds
used
to label fluids or track fluid movements. Artificial water tracers are used for inter-well tracer
tests. The interest of this study lies on natural water tracers. Even though ions sea water are
affected by chemical activities, Huseby et al., (2009, p.2) indicated that in most cases ions in sea
water only react moderately with the formation water. Such ions can be used as natural tracers of
sea water. Ions which may be used for such application include SO42-
, Mg
2+
, K
+
, Ba
2+
, Sr
2+
, Ca
2+
,
Cl-(Huseby et al., 2009, p.2).
The second option for natural tracers of water are isotopes. Hydrogen isotopes are the
best being abundant in water. Another isotope is Strontium 87Sr, a radiogenic isotope found in
high concentration in potassium rich rocks (Huseby et al., 2009, p.2). The high concentration is
transferred to formation waters with which such rocks have equilibrated. The ratio of 87Sr to the
more abundant 86Sr isotope can be used as tracers for formation water.
The choice of natural water tracers might be an economic decision rather than a choice
based on quality. Ion content data of produced water are routinely analysed as part of the flow
assurance, hence has little extra acquisition cost compared to isotopes. For this study, the
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assumptions is that there are scale risks in our synthetic reservoir which exclude the use of SO42-
as a tracer. The alternative choice is the use of Cl- ions as tracers. These ions do not move in
between reservoir phases and are not subject to portioning effects (Valestrand et al., 2008, p.2).
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3 Review of Concepts and Studies
3.1 Stochastic Optimization Techniques for History Matching
A major problem of history matching techniques is the possibility of existence of local
minima in the solution space (Hajizadeh, Demyanov, Mohamed, & Christie, 2011 p.211). It has
earlier been mentioned that gradient based history matching techniques lack the ability to
navigate through such a parameter space without being trapped in a local minima. Secondly,
accurate forecast of future reservoir performance is very important for decision making.
Hajizadeh et al.(2011, p.210) reported that simple optimization techniques have been
found to be inadequate for history matching problems. He further noted that even the Monte
Carlo Approaches were not intelligent enough for the optimization task. These problems speak to
a need for powerful optimization techniques which is able to navigate through multi-modal
parameter space to identify fitting solution models, as well as execute such task in feasible time.
Stochastic optimization algorithm have these characteristics and several have been developed
since the 1990s. Schulze-riegert & Ghedan (2007, p.1) lists some of them as follows:
Evolutionary Algorithms; Gradient techniques; Response surface modelling and optimisation on
the response surface; Hybrid schemes which couple different optimisation techniques; Ensemble
Kalman Filter Techniques. More recent algorithms were described by (Hajizadeh et al., 2011,
p.212) as follows:
Evolution Algorithms
Evolutionary Strategies (ES); Genetic Algorithm[6,7]; Differential Evolution (DE) [14]
Swarm Intelligence Algorithms
Ant Colony Optimisation (ACO); Particle Swarm Optimisation (PSO) ;Neighbourhood
Algorithm
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3.1.1 Genetic Algorithm
The genetic optimisation algorithm is a form of evolutionary algorithm based on
techniques or concepts of natural evolution and the genetic system, such
asinheritance,mutation,selection, andcrossover. An optimisation problem is defined, its
objective function is defined as the fitness function and the solution models sought are encoded
with chromosome or a string of bits such as binary numbers (Obitko, 1998). Each bit is related to
a parameter of the solution model by a function (Tatiana Tambouratzis, 2013, p.163).
It starts with the initiation of a generation of randomly generated solutions to the problem.
The process of selection follows, in which the solution are ranked based on specified fitness
criteria such as the value of the objective function. The best solutions of the population are
selected to breed a new generation. Breeding of a new set of solutions is achieved through
genetic operations. Two or more parent solution models are randomly selected from the set of
bests for the generation. There chromosomes or encoding are treated as genetic identities on
which the genetic operations are performed. Popular operations are mutation and crossover,
others include regrouping, migration, extinction, roulette wheel selection, elitism, etc. (Tatiana
Tambouratzis, 2013, p.163).A generation ends when its population size is reached. The objective
function is observed to approach closer to the target solution or fitness value with each new
generation.
3.1.2 Differential Evolution
Differential Evolution is a form of Evolution Algorithm, hence it shares the same
description and procedures with Genetic Algorithm, but differs in method of evolution. Creation
of the new generation occurs before selection is done. It used uses a specified mutation and
recombination operation to create the new generation. Rather than chromosomes, differential
http://en.wikipedia.org/wiki/Heredityhttp://en.wikipedia.org/wiki/Mutation_(genetic_algorithm)http://en.wikipedia.org/wiki/Selection_(genetic_algorithm)http://en.wikipedia.org/wiki/Crossover_(genetic_algorithm)http://en.wikipedia.org/wiki/Crossover_(genetic_algorithm)http://en.wikipedia.org/wiki/Selection_(genetic_algorithm)http://en.wikipedia.org/wiki/Mutation_(genetic_algorithm)http://en.wikipedia.org/wiki/Heredity8/10/2019 History Matching and Uncertainty Quantification with Produced Water Chemistry
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algorithm uses vectors of solution model parameters to represent solutions in the parameter space
(Hajizadeh, 2011, p.71). For mutation, three solutions from the population are randomly selected
(x1g, x2g, x3g where g denotes the generation). A mutation or mutant vector is calculated as
follows.
(Hajizadeh, 2011, p.72) EQ. 3-1The factor F controls the rate of evolution, ranging from 0 to 1. In recombination or cross over
operation, each member of the population is crossed with the mutated vector to produceand offspring
. The selection process is then implemented in which the objective function
for the parent and offspring are compared, the one with lower objective function isretained as for a minimization problem (Hajizadeh et al., 2011, p.218). EQ. 3-2
3.1.3 Ant Colony Optimisation
Swarm Intelligence algorithms are optimisation techniques based on the collective
behaviour organism such as insects, birds, etc. (Leonor Melo Francisco Pereira, 2013, p.179).
Swarm intelligence algorithms are the most recent of optimisation algorithms, they include the
Ant Colony Optimisation, Bee Colony Optimisation, and Particle Swarm Optimisation.
The Ant Colony Optimization algorithm is based on the behaviour of ants as they search
for food. Ants leave pheromones to mark their paths so other ants can follow them as they search
for food. The strength of the pheromone markers decay with time, the more frequently a path has
been taken, the stronger the accumulation of pheromones from various ants, and the more likely
this path will be taken by other ants. The longer the path taken is, the more time for the
pheromones to dissipate. Hence, the less likely other Ants will follow the path. The information
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shared through pheromone distribution allows ants to translate from random exploration to the
shortest path to the nearest food source. This behaviours of ants are modelled in optimization as
solution searches by a number of ants in a colony. When one ant finds a better solution based on
defined criteria, a pheromone like property of its search influences the other ants to search more
in the vicinity of the solution found (Hajizadeh et al., 2011, p.214). This however risks trapping
the process in a local minima, hence some parameters or weighting are applied to the decision
criteria so that the ants at times deviate from the pheromone informed decisions in order to create
a better exploration of the solution space.
3.1.4 Particle Swarm Optimisation
Particle Swarm Optimization (PSO) was originated by Kennedy J, Eberhart R in 1995
Hajizadeh et al., 2011, p.219). It is an optimization techniques based on the movement of flock of
birds and school of fishes. A set of particles, each representing a solution to the defined problem,
is randomly initialized. Subsequently two factors influence the next movement of each particle as
they search for better solution:
1. pbest: - a particles best known position in terms of the optimization target.
2. gbest: - a global best known position from among the swarm of particles.
They are updated in each iteration and used to calculate the particles next movement as follows:
Updating:
EQ. 3-3 where EQ. 3-4Velocity:
( ) ( ) EQ. 3-5
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EQ. 3-6(Hajizadeh et al., 2011, pp. 219-220)
Where
and
are as defined earlier
denotes a particular particle in the swarm is the velocity of the particle of index in a specified dimension for the next
iteration in a multi-dimensional solution space.
and are randomly generated real numbers between 0 and 1 and are weighting used to control the focus of exploitation of a local area versus
exploration of the solution space.
is a weighting factor which controls the rate of convergence of the algorithm represents the iteration count
The particle swarm optimization has various variants from this basic definition. They may differ
on the method of updating the velocity, choice of gbest, updating of particle position, etc. Below
is a flow diagram of the process.
Start
Initialize Z particles in
Solution space i=1
Evaluate Particles
Position for fitness
Compare current
Particles position with
pBest
Update the Value of
PBest
Do for Particle i, for
i=1 to Z
Update gBest
Calculate Particle is
new position using
EQ.3-5
Update Particle is
position
Yes i=Z
Is stopping
criterion met?
Yes
End
No
Next Iterations
Set i=1
Figure 3-1 Work Flow for Particle Swarm Optimization
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3.1.5 Use of Particle Swarm Optimization for Reservoir History Matching OptimizationProblem
(Hajizadeh et al., 2011) conducted a comparative study of various stochastic optimization
algorithms. This study was conducted on two relatively well known reservoir models, the Teal
South reservoir and the PUNQS3 reservoir model with 45 parameters. The authors considered the
following algorithms: Differential Evolution- Best Variant; Differential Evolution; Particle
Swarm Optimization; Ant Colony Optimization; Neighbourhood Algorithm. The study reached
the following conclusions (Hajizadeh et al., 2011, p.238):
1. All the stochastic algorithms performed well compared to gradient based algorithms.
2. That for all the algorithms studied, Differential Evolution-Best and Particle Swarm
Optimization had the fastest convergence, as well as achieved the lowest misfit solutions.
3. That all the algorithms had uncertainty bounds which included the truth case
Ant Colony Optimization had the smallest span of uncertainty, followed by Particle Swarm
Optimization, these differences are very small. Several other studies have been conducted using
particle swarm optimisation (Lina Mohamed, Christie, & Demyanov, 2011), (Linah Mohamed,
Christie, & Demyanov, 2009), (Hajizadeh, 2011b), (Arnold, Vazquez, Demyanov, & Christie,
2012), (Vazquez, MacMillan, et al., 2013), (Vazquez, McCartney, et al., 2013).
3.1.6 Multi-Objective Particle Swarm Optimization.
History matching problems will often have to consider different kinds of data. For
example history matching of a reservoir may involve data from the well bottom-hole pressure,
gas oil ratio, production volumes or rates, water cuts, etc. These data come in different numerical
ranges, a summation of all into a misfit definition will result in those with high numerical range
overshadowing those with low numerical range. An inefficient optimization will result.
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Where F is the objective function. EQ.
3-7
The solution to this problem for single objective optimization is to apply weights c1, c2
and c3 (see EQ. 3-7) in order to control the contribution of misfit components. Determination of
values of these weight is debateable. An alternative approach to this problem is the use of multi-
objective optimization. Data of different numerical range and type are separated different
objectives for concurrent optimization. It eliminates arbitrary combination of dissimilar data into
misfit functions. In a recent study, Lina Mohamed et al.(2011) conducted a comparative study of
Single Objective Particle Swarm Optimization (SOPSO) and Multi-Objective Particle Swarm
Optimization (MOPSO). The study was conducted as a history matching task on IC Fault
Reservoir model from Imperial University, UK. The authors concluded as follows:
That the MOPSO was twice faster than SOPSO in convergence and obtained good fitting
models to the history matching problem.
That MOPSO obtained a more diverse set of solution models compared with SOPSO.
That while SOPSO gave a narrower uncertainty range, MOPSO resulted in a more robust
and more accurate uncertainty definition which included the truth case.
This study will use Multi-objective Particle Swarm Optimization for the mentioned benefits.
3.1.7 Optimal Solutions in Multi-Objective Optimization: Pareto Front
In single objective optimization problems, an optimal solution is selected based on the
value of the misfit function. In multi-objective optimization the task of selecting optimal
solutions becomes a bit more complex as the solutions represent different trade-off between
objectives in terms of dominance (Lina Mohamed et al., 2011,p.2). Veldhuizen & Lamont (1997,
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p.2) indicated that one of the key ideas for dealing with this problem of selecting optimal
solutions is the concept of Pareto Optimality. Pareto optimal solutions stems from the definition
of Pareto Dominance.
Let us view two solutions of a multi objective optimization problem as vectors and, wherethere are p objective functions.
and is said to dominate if and only if is partially less than (for minimization problems).i.e
{ } { } EQ. 3-8Based on this definition we now define the pareto optimal solution set as solutions that are not
dominated by any other solution. This means that for N number of evaluated solutions, solution
is pareto optimal if { } { }
{ }
EQ. 3-9
The pareto set when plotted graphically is called the pareto front. It physically represents the
range of optimal trade-off between the objectives.
3.2 Uncertainty Quantification for Forecast
3.2.1 Definition of Uncertainty
Uncertainty is the lack of assurance about the truth of a statement or the exact magnitude
of an unknown measurement or number (Schulze-Riegert & Ghedan, 2007, p.2). Uncertainty
may result from an actual lack of knowledge, a difficulty in measurement or errors in
measurement.
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For a reservoir, the major driver of uncertainty is heterogeneity of the reservoir. Most
reservoir data are only reflective of measurements at the well location. Inferences have to be
made about locations in between wells. Heterogeneities occur at all scales of the reservoir, from
microscopic pore scale to the megascopic properties.
Heterogeneity in reservoir characterisation translates to uncertainty in simulation outputs
and forecasts. Uncertainties in reservoir characterisation were grouped by Schulze-riegert &
Ghedan (2007, p.7) as follows.
Uncertainty in Geological Data: Uncertainties due to measurement errors, selection or
interpretation of geological data of the reservoirs
Uncertainty of Geological Data: Uncertainties inherent from the complexity of reservoir
geology or lithology. Issues and interpretation from of sedimentation, lithology, and mapping.
Uncertainty in Dynamic Reservoir Data: Uncertainty in properties that affect the flow of
fluids.
Uncertainty in Reservoir Fluids Data: Composition of reservoir fluids retains some
uncertainties as to the extent to which obtained samples are representative of the whole field.
The many sources of uncertainties means that it is impossible to totally eliminate uncertainty
from reservoir model. It is imperative that we quantify the uncertainty in the results of reservoir
models and simulation to better inform of the limits of their applicability.
3.3 Uncertainty Quantification Method: Neighbourhood Approximation Using Bayes
Theorem (NA-Bayes)
Bayesian framework was used for uncertainty quantification in this study. It has been
applied severally in in similar studies by several scholars (Christie, Demyanov, & Erbas, 2006),
(Christie, Subbey, & Sambridge, 2002), (Sambridge, 1999), (Hajizadeh et al., 2011).
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It is important to note that uncertainty quantification is also necessitated by the
inadequacy of misfit values as a measure of accuracy of a solution model. By definition misfit is
a function of the difference between observed values and simulated values of reservoir
performance.
EQ. 3-10However it is not just simulated values that are subject to inaccuracies, observed values are
subject to measurement errors. Accounting for this error, we refine the misfit definition as
] (Christie et al., 2006, p.145)EQ. 3-11
Hence in actual fact, misfit values are the difference in errors associated with observed data and
simulated data. Misfit may not reflect direct relations to the truth value of a reservoirs
performance.
3.3.1 Bayes Theorem
Bayes theorem is a method of inference which allows us to update the probability
estimate for a hypothesis as added evidence is acquired about the hypothesis (Christie et al.,
2006, p.4).
EQ. 3-12Bayes rule stated above can be summarised as stating that P(H) - Priorprobability of the hypothesis before any Evidence; P(H|E) - Posterior probability of
hypothesis given the evidence; P(E|H)-Likelihood of the evidence given the hypothesis or
Probability of observing the evidence in the event of the hypothesis being true; P(E) -
Marginal Probability of the evidence independent of any particular hypothesis.
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Relating Bayes rule to reservoir history matching problems, the models M under investigation are
the hypothesis H, the historic production data or Observation O is the Evidence. We can rewrite
the Bayes Rule using the new notation as follows: EQ. 3-13(Christie et al., 2006, p.3)
is the posterior probability, while is the prior probability. The marginalprobability of the evidence which is the denominator is now expressed as the Bayesianintegral. The Evaluation of the posterior probabilities entails the evaluation of three elements
1. Prior Probabilities 2. Likelihood of
Observations
3. Bayesian integral expressing
Probability of the observation
The prior probabilities are evaluated from the prior information obtained from the reservoir on
the variability of the parameters describing the uncertain properties of the reservoir.
3.3.2 Likelihood of Observation
The evaluation of the likelihood is based on Gaussian error statistics. The likelihood is defined as
the negative exponent of the misfit between observations and simulation values. This is
expressed in mean squares form below:
(Christie et al., 2006, p.4) or (Sambridge, 1999, p.3) EQ. 3-14
EQ.
3-15
(Sambridge, 1999, p.3). Where C is the covariance matrix of the observation data. For a single
parameter the definition of misfit simplifies as EQ. 3-16
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Where do is the observed data, g (m) is a function of the model, or simulation result for the
model.
3.3.3
Bayes Integral: Resampling by NA-Bayes
A Bayesian integral is contained in the definition of the normalizing factor in theexpression for Bayes rule. Bayesian integrals are evaluated using Monte Carlos integration:
EQ. 3-17Using Monte Carlos Integration
EQ. 3-18
Where is the density distribution of the sampled models drawn from the solution space inthe forward solution earlier described? Difficulties arise in evaluating the relation as the density
distribution with which the models space is sampled in the optimization setups are usually
unknown. The solution to this problem is to re-sample the solution space in such a way that the
density distribution of the samples equals the probability distribution, hence they cancel out.
EQ. 3-19This can be executed using Neighbourhood Approximation Algorithm
3.3.4 Neighbourhood Approximation and MCMC Walk
Makov Chain Monte Carlos random walk have the unique property that when used to
sample a given probability distribution based on set rejection criteria, the Markov Chain will
have a distribution that is equal to the probability distribution of the sampled ensemble.This property is what we need to evaluate the Bayesian integrals using Monte Carlo integration.
However, one of the impediments to using this approach is that we do not have a full
detailed description of the probability distribution in the solution space. The ensemble of models
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are only representative. This is where neighbourhood approximation of the solution space comes
in. Using voronoi cells, the entire volume of the solution space is described by an approximation
of the actual probability. Voronoi cells are nearest neighbour regions in the solution space
defined around each model in the solution ensemble (see figure 3-1), they have the properties of
being space filling polyhedral, with their size, shape and volume automatically adapted to the
distribution of the models in the ensemble (Sambridge, 1999a, p.4). The spacing filling attribute
allows the points within a voronoi cell to be assigned a probability equal to the probability of the
model around which it is defined.
Figure 3-2Voronoi cells for ten random points (models) is a solution space. b. The updated
Voronoi cells after 100 points are sampled and interpolated using Gibbs sampler.
The sampling of the approximate probability distribution formed using voronoi cells is now
accomplished using the MCMC random walk. The MCMC variant used is the Gibbs Sampler
Algorithm. The Gibbs Sampler selects a model by taking random sized step in the direction of
each dimension of the solution space in turn (Sambridge, 1999). When it has stepped in all
dimensions, a parameter vector representing a model results. The Gibbs sampler implement
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typical MCMC rejection check on each step, this turns the sampling to select models of high
probability, hence following probability distribution in the solution space (Sambridge, 1999a,
p.5).
3.3.5 Bayesian Credible Intervals
A Bayesian credible interval is an interval in which the probability of find a truth caseor say the solution model is (Levy, 2007). It offers a convenient way of expressinguncertainty.
3.4
Review of Empirical Studies on Improving History Matching by Adding Data onInjected Sea Water Production
One of the more recent studies on using tracer information for improved history matching
of a reservoir was carried out by Valestrand et al.(2008). The study investigated the effect of the
use of partitioning gas tracer data in the history match of a reservoir for the determination of the
permeability and transmissibility Multipliers. This study was carried out on the synthetic
reservoir with various realistic features coupled. Ensemble Kalman filter (EnKF) was used in
updating the reservoir properties permeability and transmissibility. The estimation using the gas
tracer data was successful in estimating transmissibility and permeability that provide as good
match to history data, the control case without the gas tracer data was not successful in this
regard. Valestrand et al.(2008) concluded that partitioning gas tracer data was of crucial
importance in successfully estimating the reservoir properties.
Huseby et al.(2009) carried out a similar study using the Ensemble Kalman filter method.
Their study however was focused on water tracers and considers ordinary and natural water
tracers. The study was conducted using the model 2 of the 10 th SPE Comparative Solution
Project. The model is derived from a part of the North Sea Brent Sequence. The inversion
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problem was to estimate the reservoir permeability and porosity. Three cases of history matching
were considered: using oil rate and water cut production data only; using the natural tracer SO42-
with oil rate and water cut production data; and using ordinary inter-well tracer data. The three
cases were compared based on mean square error of their estimation the true porosity and
permeability of the reservoir. The result showed that for both porosity and permeability, there
were only slight differences between estimations done without tracers, and with ordinary tracers.
However, the estimations done using natural tracers showed a marked improvement in quality
with much lower error values.. The study also noted the lack of explanation for the better
performance of natural tracers than ordinary tracers, since the former do not carry
complementary information on water injection sources. The authors concluded that tracer data
were underexploited as a source of knowledge about reservoirs.
Arnold et al.(2012) carried out a study on the value of adding produced water chemistry
as tracer of injected sea water, to further constrain the history matching of the PUNQS3 reservoir
model. The study was carried out using single objective Particle Swarm Optimisation. It
considered well bottom-hole pressure, oil production rate, gas oil ration, water production rate
and well tracer data. The cases with tracer data and without tracer data were compared. Based on
misfit calculated as mean square error from the history date, it was found that out of five trials of
each case, only one case with tracer data achieved very low misfit. A second comparison was
made on the bases of clustering of the solution models in parameter space, and did not find any
considerable improvement due to tracer data. However the study found that tracers reduced the
number of acceptably matched minima points from the parameter space. The study concluded
that adding tracer data did not harm nor greatly improve the quality of the history match, but
made significant improvements to forecast.
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Vazquez et al.(2013) extended the methods of the study by Arnold et al.(2012) to an
actual real field, the Janice Field. The reservoir model provided for the study was history match
by the operator. The aim of the study was not strictly comparative, the study analysis found that
the conventionally matched model was mismatched to produced sea water fraction of the three
wells considered. Based on this, it identified new geological uncertainties in the reservoir model
and a new history match was carried out using Particle Swarm Optimisation and sea water
production tracer data. In terms of sea water fraction, it achieved a significantly better match for
one well, and slightly better match for the remaining two well. Using the Bayesian framework,
the study made uncertainty quantifications for the field forecasts, and developed scale risk
assessment for the field.
Vazquez et al.(2013) conducted the most recent study on effect of the composition of
produced water on history matching a one dimensional reactive reservoir model. The study was
not comparative of the non-tracer, rather it investigated connectivity and reactions between the
producer and injector in two cases which differed based on the amount of produced water
chemistry data available. It concluded that produced water chemistry had the potential to provide
the information sought on dispersivity of the connection flow paths between the wells, it also
considered it a successful application of Particle Swarm Optimisation to a reactive reservoir
model.
3.5 Problem Statement
The problem to be investigated by this study is the determination of the extent of improvements
to reservoir history match and uncertainty quantification induced by the used of produced water
chemistry data to specify historic production of injected sea water fractions. It has been proposed
by several studies reviewed in the preceding section that since injected sea water carried
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complementary information on flow paths within the reservoir, its addition as a constraint to
reservoir calibration should improve the quality of history match and also reduce the amount of
uncertainty in forecast. Specifically this study aims to answer the following questions.
Question 1: Does adding natural tracer data reduce the mean square error misfit achieved by
sampled models with reference to oil rate and bottom-hole historical data?
Question 2:Does adding natural tracer data generally reduce the range of uncertainties specified
by Bayesian credibility intervals over the history match and forecast period?
Question 3: Does adding natural tracer data reduce the range of uncertainties specified by
Bayesian credibility at the terminal point of the forecast period?
While none of the earlier works has sought to compare the effect of adding natural sea water
tracer data to history matching by measuring the range of uncertainties, Arnold et al.(2012) had
observed that it made improvements to forecast generally. The comparison by misfit of sampled
models has been a bit more complicated due to earlier studies use us single optimization
techniques, which requires addition or removal of tracer data points before misfit values could be
compared (Arnold et al., 2012, p.6). Also, the combination and weighting of the objective
function for oil rate, water rate and natural chemical tracers for sea water in earlier studies
prefixes the combinational relationship between these objectives. While this does not hamper the
optimisation schemes from finding good solution models, it does limit the extent of exploration
in the search for good fitting models. This study will be carried out using multi-objective particle
swarm optimisation to allow a free comparison of misfit values and also maximise the space
searched by the optimisation algorithm. The choice of optimisation algorithm has also been
informed by the earlier reported works on comparative study of optimisation techniques (Linah
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Mohamed et al., 2009) and multi-objective particle swarm optimisation (Lina Mohamed et al.,
2011). This value of improving history matching has been earlier discussed in the introduction.
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4 Data Summary: PUNQS3 Reservoir Model4.1 OriginThe PUNQS3 is a synthetic reservoir model based on an actual reservoir developed by Elf
petroleum. The synthetic case was initially developed for the PUNQ (production forecasting with
uncertainty quantification) project sponsored by the European Community. In the PUNQ project
ten partners from industry, research institutes and universities are collaborating on research on
uncertainty quantification methods for oil production forecasting (Soleng, 1999, p.1). It has
however become a benchmark for testing methods in history matching and uncertainty
quantification (Arnold et al., 2012, p.2).
The reservoir model consist of 19x28x5 grid blocks, of which 1761 blocks are active. It is
bounded to the east and south by a fault, the north and west are linked to a strong aquifer. It also
includes a gas cap, while six well are located around the gas oil contact. There were no injector
wells since the reservoir had a strong aquifer support.
The production scheduling is based on the real reservoir. Wells are under production constraint
based on flow. The scheduled flow periods are for a first year of extended well testing, followed
by a three year shut-in period, before field production commences. During field production, two
weeks shut-in period for each year is included for each well to collect shut-in pressure data. Total
production period is for 16.5years or 6025 days.
4.2 Available Reservoir DescriptionThe geological description of the reservoir as provided by imperial college is given below
(Gologil Diption fo PUNQS3 Rvoi Modl, n.d.).
The layer thickness is of the order of 5meters in thickness, it played a major role in geological
interpretation. The sediments were deposited in a deltaic, coastal plain environment. Layers 1, 3,
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and 5 consist of fluvial channel fills encased in floodplain mudstone. Layer 2 represents marine
or lagoonal clay with some distal mouthbar deposits; and layer 4 represents a mouthbar or
lagoonal delta encased in lagoonal clays.
Ly 1, 3, nd 5 hv lin tk of high -porous sands ( > 20 %), with an azimuth
somewhere between 110 and 170 degrees SE. These sand streaks of about 800 m wide are
embedded in a low porous shale matrix ( < 5 %). The width and the spacing of the streaks vary
somewhat between the layers. A summary is given in the table below.
In layer 2 is a marine or lagoonal shale in which distal mouthbar or distal lagoonal delta occur.
They translate into a low-porous ( < 5%), shaly sediment, with some irregular patches of
somewhat higher porosity ( > 5%).
Ly 4 ontin mothb o lgoonl dlt within lgoonl ly, o flow nit i expected
which consists of an intermediate porosity region ( ~ 15%)with an approximate lobate shape
embedded in a low-porosity matrix ( < 5%). The lobate shape is usually expressed as an ellipse
(ratio of the axes= 3:2) with the longest axis perpendicular to the paleocurrent (which is between
110 and 170 degrees SE).
Layer Facies Width Spacing
1 Channel Fill 800 m 2-5 km
2 Lagoonal Shale
3 Channel Fill 1000 m 2-5 km4 Mouthbar 500-5000 m 10 km
5 Channel Fill 2000 m 4-10 km
Figure 4-1 Expected facies with estimates for width and spacing of major flow units
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5 Methods
5.1 Work Flow Diagram
Start
Definition of Study
Objectives-PUNQS3
Reservoir Model
Parameterisation of
PUNQS3 Reservoir
Model
Define Uncertain
Parameter
Define History
Data to be
Matched
Generation of
Simulation Files
Determination of
Range of Uncertain
Parameters
Generation of
Distribution Files
for Optimisation
Generation of History
Data from Truth
Case: Blind to
Parameterisation
Determine Initial
Values of
Variance for
History Data
Modification of
PUNQS3 Model to
include Water
Injectors and Water
Tracers
Case1 PWC:
Selection of History
Data to Match
Include Sea
Water Production
Rate History
Determination of
Optimisation
Objective Functions
Setup Optimisation
Software: RAVEN
Execute Multi-
Objection
Optimisation : PSOfor 3000 Iteration
Determine
Convergence Point:
Number of Iterations
Repeat PSO
Optimisation for
Converged Number
of Iterations
Setup Ensemble for
Forecast and
Uncertainty
Quantification:
RAVEN
EXECUTE:
PPD Approx.
MCMC Walk
Is No. of Sampled
Models Adequate?
Review Variance
Values to Modify
Ensemble Density
Execute Two
additional Runs of
PSO Optimisation
Setup the 3
ensembles jointly for
forecast and
Uncertainty
Quantification:
RAVEN
EXECUTE
PPD Approx.;
MCMC Walk;
Simulations for
forecast;
EXECUTE: CalculateBayesian Credibility
Intervals P10, P50 &
P90
Case2 No PWC:
Selection of History
Data to match
Exclude Sea
Water Production
Rate History
Execute Three Runs
of PSO Optimisation
at Converging
Iteration Number
Setup 3 ensembles
jointly for forecast and
Uncertainty
Quantification:
RAVEN
EXECUTE
PPD Approx.;
MCMC Walk;
Simulations for
forecast;
EXECUTE: Calculate
Bayesian Credibility
Intervals P10, P50 &
P90
Result Analysis and
Conclusions
End
Figure 5-1Work Flow Diagram
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5.2 PUNQS3 Problem: Uncertain Parameters
The PUNQS3 reservoir model was generated synthetically. The reservoirs description (see
Data Summary) was developed to match the synthetic reservoir. The reservoir model without the
porosity and permeability data, was distributed to researchers who were asked to invert the
production data to estimate the permeability and porosity. This study will be working with the
same problem configuration to determine the porosity and permeability distributions for the 5
layers on the PUNQS3 model. However our focus is to assess impact of adding injected sea
water production data as an additional constraint to the history matching method.
5.3 Modifications to the PUNQS3 and Historical Data
The PUNQS3 was initially designed without any
injection wells due to the strong aquifer support
modelled. It is imperative that sea water is injected into
the reservoir for this study, hence four Injections wells
have been added to the reservoir as shown in the figure
above. With this modification, the original history data
distributed with the reservoir model can no longer be
used for this study. These modifications necessitate the
generation of a new history data using the truth case data
provided at the PUNQS3 website of Imperial College
(Gologil Diption fo PUNQS3 Rvoi
Modl, n.d.).
5.4 ParameterisationThe two uncertain reservoir properties were identified as porosity and permeability.
Figure 5-2 Injectors and Producer
Wells on the PUNQS3 Reservoir
odel
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5.4.1 Regions and Justification/ Generation of Simulation Files
The reservoir description for the PUNQS3 indicates the existence three layers (1, 3 and 5)
which have fluvial sand channels embedded in a flood plain. The description also highlights the
direction of these sand channels as between 110 to 170 degrees azimuth. The sand channels had a
minimum width of 800m and spacing of 2 to 5 km.
For these sand channels we assume that the channels direction is mid-way between the
specified range at 145 degrees azimuth. This is to reduce the number of required parameters,
variations of 35 degrees in azimuth is not expected to have a major impact on the reservoir
performance. The parameterisation will be based on regions to capture the heterogeneity across
layers of the reservoir. Since the position of the sand channels is unknown, as region scheme has
been adopted which allows flexibility in the location and width of the sand channels, while also
minimizing the resulting of geometrically unrealistic models.
As illustrated in the Figures 5-4 to 5-8 below, the parameter regions have been defined
diagonally in the approximate direction of 145 degrees azimuth. The Larger regions whose
width(448m) is about half the minimum sand channel width(800m) described is alternated with
two smaller regions of width (256m) in order to build in reasonable flexibility on the location of
the sand channels. This is at the expense of having some poor models with sand width less than
800m. The same parameter regions is used in layers 3 and 5, being mindful that the sand
channels in in layer 5 have widths of about 2km. This arrangement was adopted with the
expectation that the best models will identify several adjacent regions to be of similar high
permeability to form the required sand body. This effect was observed for one of the low misfit
models, its first layer is visualized in Figure 5-3. There are a total of 17 parameter regions in
layer 1, 14 parameter regions in layers 3 and 5 respectively, and 18 in layer 4.
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Note that similar colours are not related. They all mark different parameterisation regions.
Figure 5-6 Layer 1
ParameterisationFigure 5-5 Layer 2
ParameterisationFigure 5-4 3 Layer 3
arameterisation
Figure 5-8 Layer4
ParameterisationFigure 5-7 Layer 5
Parameterisation
Figure 5-3Sample
Optimization Result-Qualitative Permeability
ap-light blue shows highererm.
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Layers 2 and 4 from the reservoir description are low permeability shale or clay. Layer 2
has no prominent flow unit, while layer 4 has a lobate shaped flow unit embedded in the lagoon
clay. Layer 2 has been parameterised as a single parameter region (See Figure. 5-4). An
arrangement of several block region has been made, with small block interconnecting them. The
idea is to be able to form an approximation of a lobate shape in many ways with several
selections. On the total, the PUNQS3 reservoir model has been parameterised into 66 parameters.
The table below lists the parameters by layer and shows the naming convention.
Table 5-1 List of Parameter for PUNQS3 ReservoirLayer1 Layer2 Layer 3 Layer4 Layer5
$L1P $L2P $L3P2 $L4P1 $L5P2
$L1P1 $L3P3 $L4P2 $L5P3
$L1P2 $L3P4 $L4P3 $L5P4
$L1P3 $L3P5 $L4P4 $L5P5
$L1P4 $L3P6 $L4P5 $L5P6
$L1P5 $L3P7 $L4P6 $L5P7
$L1P6 $L3P8 $L4P7 $L5P8
$L1P7 $L3P9 $L4P8 $L5P9
$L1P8 $L3P10 $L4P9 $L5P10
$L1P9 $L3P11 $L4P10 $L5P11
$L1P10 $L3P12 $L4P11 $L5P12
$L1P11 $L3P13 $L4P12 $L5P13
$L1P12 $L3P14 $L4P13 $L5P14$L1P13 $L3P15 $L4P19 $L5P15
$L1P14 $L4PA
$L1P15 $L4PB
$L1P16 $L4PC
$L4PD
$L4PE
$L4PF
5.4.2 Correlation of Porosity and Permeability
Hajizadeh et al.(2011) in his study indicated the existence of a correlation between
porosity
and permeability for the PUNQS3 reservoir model. The report also included a correlation
between vertical and horizontal permeability. The relations are given below.
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These relations are used for this study to minimize the number of parameters required to fully
capture the uncertain permeability and porosity of the reservoir. The parameters will be used to
define porosity, while the porosity will be used to calculate the horizontal permeability according to above relations. Vertical permeability is calculated from the relations withhorizontal permeability. Permeability is assumed to be equal in all horizontal directions.
5.4.3 Parameter Distribution
The prior distribution of the parameters has been decided based on the PUNQS3 reservoir
description. The porosity variation are assumed to be uniform over the range. The range or
distribution were assigned based on the layers. Summary of distributions by layers is given
below.
Table 5-2 Distribution of ParameterLayer Distribution Porosity Range (%)
1 Uniform 15-30
2 Uniform 5-10
3 Uniform 15-30
4 Uniform 5-15
5 Uniform 15 -30
5.5 Selection of Histories to Match and Objective Functions for Optimisation
This study is comparative of two cases of history match. The first case use the additional
constraint of injected sea water produced data and is denotes Case 1:SWTP (Sea Water Tracer
Production). The second case excludes the water tracer data from the history match, and is
denoted Case2: NSWTP (No Sea Water Tracer Production). Case-C is a repeate of Case 1 made
as a control.
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5.5.1 Case 1:
5.5.1.1 Tracer Data
For this case tracers have been added to the injector wells. The same tracer is used for all
four injection wells to model the nature of natural water tracers which do not have
compli