iptc-17945-abstract forward modeling of reservoir quality

IPTC-17945-Abstract

Forward Modeling Of Reservoir Quality In The Oligocene-Miocene Siliciclastic Series, Offshore NE Malaysia, And Implication For Exploration Girard Jean-Pierre (1), Matthews James (1), Teinturier Stéphane (1), Walgenwitz Frédéric (1), Jeanne Pelé, Baudot Gautier (2) (1) TOTAL E&P, Pau, France; (2) TOTAL E&P, Kuala Lumpur, Malaysia

This paper was prepared for presentation at the International Petroleum Technology Conference held in Kuala Lumpur, Malaysia, 10-12 December 2014. Contents of the abstract have not been reviewed by the International Petroleum Technology Conference and are subject to correction by the author(s). This material does not necessarily reflect any position of the International Petroleum Technology Conference, its officers, or members. Copyright is retained by the author(s). Contact the author(s) for permission to use material from this document.

Abstract Reservoir quality modeling was conducted on the thick (5 km) series of Oligocene-Miocene siliciclastic sediments in the Malay basin, offshore NE Malaysia (blocks PM303-PM324) using the Touchstone software. The goal was threefold: 1) constrain the variation of reservoir quality as a function of burial depth/temperature and sand composition; 2) define maximum depth at which acceptable reservoir quality is preserved; 3) provide a range of expected porosity-permeability for deeply buried prospects. Calibration of the model was done by use of quantitative mineralogy-petrography available from nearby wells located to the NE and SW of the prospected blocks. At these locations, similar tertiary sandstones exhibit sub-litharenite to litharenite compositions with highly variable clay content (0-50%), limited quartz cementation and significant diagenetic kaolinite. Quality of available point-counting data was not perfect and adjustments were made to correct for obvious inaccuracies. Burial/thermal histories at locations of interest were derived from 1D Genex basin modeling. In the absence of constrain on the timing of hydrocarbon emplacement, the latter was estimated using the Touchstone model by setting activation energy to 59kj/mole and tuning timing of HC charge until proper matching of quartz cement was obtained. In spite of all these uncertainties, the predictive model provided valuable information for preliminary exploration considerations: 1) compaction is the primary factor of porosity loss over the investigated burial/thermal range (0-5km, 0-175°C); 2) intergranular porosity falls below ~10% by ~2.5 km depth in cleanier sands (<5% clay) and by ~1.5 km in shalier sands ( >5% clay); 3) impact of quartz cementation on reservoir quality is very limited below 120°C due the young age (7-25Ma) of sediments; 4) early timing of HC charge is key to the preservation of reservoir quality (quartz retardation) in deeply buried (>120°C) prospects. These conclusions were partly verified in the first well drilled in the exploration zone.

Paper No. 17945-Abstract

Forward modeling of reservoir quality in the Oligocene-Miocene siliciclastic series, offshore

NE Malaysia, and implication for exploration

Jean-Pierre Girard, TOTAL, Pau, France J. Matthews, S. Teinturier, F. Walgenwitz, J. Pelé, G. Baudot (TOTAL)

OUTLINE

Context and objectives Background information & input data Touchstone Modeling - Forward prediction of RQ

Conclusions

Slide 2

Paper # 17945-abst • Forward modelling of reservoir quality, offshore Malaysia.. • JP. GIRARD

CONTEXT AND OBJECTIVES

Work done (2009-2010) as a preliminary guide for exploration in the Tertiary series off shore Malaysia Main objectives Build a reservoir quality model for the Oligocene-Miocene sands in the Malay basin (PM303 & 324)

• Petrographic and basin modeling data • Touchstone software (GeocosmTM)

Perform forward modeling to evaluate pre-drill reservoir quality of the entire Oligocene-Miocene section

• Constrain possible variation in Φ-k values for prospects a.a.f. depth/temp • Define economic basement (depth with accceptable RQ)

Slide 3

BACKGROUND INFORMATION

AND INPUT DATA

LOCATION MAP - BLOCKS PM303 & PM324 Slide 5

Peninsular Malaysia

PM303 PM324 Total Operator 70%

Carigali 30.0 %

Off shore Malaysia Oligocene-Miocene sand-shale series HP/HT area (170-200oC & 600-800 bar)

THICK TERTIARY SEDIMENTARY SERIES Slide 6

Extensive exploration done at < 3 km What about deeper targets ?

Syn Rift continental

Early postrift lacustrine

Post Rift fluvial-shallow marine

Fluvial-deltaic

SE

Bujang

Inas

Sepat

Guling

COASTAL PLAIN

MARINE or LACUSTRINE SHALES

MARINE SHALES

K

J

I

HF

E

Semangkok-Timur

Laba-BaratLarut

Tapis

LM

NW

DELTAIC SANDS

N

THER

MA

L

SUB

SID

ENC

EEX

TEN

SIO

NC

OM

PRES

SIO

N

FLUVIO-DELTAIC SAND TO OFFSHORE SHALES

?

CO²? CO²?

D

Water depth ~500 m

Water depth ~0-50m

Water depth up to 300 m

??

Unexplored HPHT domain

CALIBRATION WELLS USED IN THE STUDY Slide 7

Analog wells in or within ~50km of prospective blocks Samples mainly in Lower Miocene sandstone units Burial depth range: 1.2-2.9 km

Resak-A6 Fm I & J (2.0-2.7 km)

Laba Barat-1 Fm E, H & I (1.2-2.6 km)

LABA BARAT-1

IRONG BARAT-9

SEMANGKOK TIMUR-2SEROK-2&4

TELOK-TIMUR-1

TELOK-1

DULANG-6&A17

PM-303 PM-324

KENARONG

PERTANGBUNDI

ARING-1 JENERA-1

RESAK

South Bundi-1 Fm E & H (1.2-2.3 km)

Kenarong-3 Fm E, F, H & I (1.5-2.9 km)

25km

SANDSTONE COMPOSITION - QFL PLOT Slide 8

90

80

70

60

10

20

30

40

Q

LF

KERANONG-3LABA BARAT-1RESAK A6SOUTH BUNDI-1

QUARTZ

FELDSPARS LITHICS

Large variability !

Two lithological trends

Lithic trend - rich in Rock Fragt. (Resak & Kenarong)

Arkosic trend – rich in Feldspar (Laba Barat & South Bundi)

(TS point-counting data)

Potential for significant differences in diagenetic effects & Reservoir Quality

0

10

20

30

40

50

0 10 20 30 40 50

Total cements %

IGV

(min

us m

atrix

) %

Unit DUnit EUnit FUnit HUnit IUnit JUnit L

Φ=0%

Φ=10%

Φ=20%

Φ=30%

Φ=40%

MAIN DIAGENETIC FEATURES Slide 9

PyriteSideriteKaolinite

Quartz overgrowthsSecondary porosityIntercrystalline microporosityMechanical compaction

Deposition 0 Ma

<100’s m <1km

HC

cha

rge

Late Fdps dissolution

Top hardoverpressure

?

Main factor of porosity loss

is compaction

DATA QUALITY CONTROL & CLEANING Slide 10

Data quality revealed highly heterogeneous, and insufficient for South Bundi & Laba Rabat wells

=> Only Kenarong & Resak (lithic trend) were used for model calibration

QUARTZ

FELDSPARS LITHICS

0

10

20

30

40

50

60

0 10 20 30 40 50 60

Intergranular volume %BSV

Sum

Cla

y M

atri

x %

BS

V Kenarong-3

Resak-A6

Clean sands

Model used two different lithologies : - SHALY LITHIC SANDS - CLEAN LITHIC SANDS

Not used for model calibration

TOUCHSTONE MODELING OF RQ

( ) p ( ) ( )

TOUCHSTONE MODELING Forward modeling of sandstone reservoir quality

INPUT DATA • petrographic data (thin sections) • petrophysical data (Φ k) • burial-P-T history data (basin model)

Phi (%) K (mD)

CALIBRATION • calibration wells – analogs

PREDICTIONS • probabilistic Φ-k distributions

CALIBRATE

TOUCHSTONE

(Qz cmt, ɸinter, IGV)

PROBABILISTIC ɸ-k PREDICTION

ON PROSPECTS

Time

Dep

th T°σeff.

Mechanically andchemically stable

Mechanically stableChemically unstable

Mechanically andchemically unstble

From Bloch (1994)

Arkosic arenite

Ark

oses

Litharenite

0

5

10

15

20

25

30

0 5 10 15 20 25 30

q

BEFORECALIBRATION

Measured Qz cmt (%)

Calc

ulta

ted

Qzc

mt(

%)

0

5

10

15

20

25

30

5 10 15 20 25 30

0

AFTERCALIBRATION

Measured Qz cmt (%)

Calc

ulta

ted

Qzc

mt(

%)

Burial History(z, t, σeff, Sw)

Petrography(point counting)

Petrophysics(Phi-K plug)

ANALOGSs composition

and texture

PROSPECTBurial History

CALIBRATED

MODEL

TOTAL POROSITY a.a.f. TIME Slide 13

Kenarong-like model - WATER-BEARING RESERVOIRS

0

5

10

15

20

25

30

35

40

45

50

0510152025

Time (Ma)

Tota

l por

osity

%

D Total Porosity

E Total PorosityF Total Porosity

H1 Total PorosityH2 Total Porosity

I Total PorosityJ1 Total Porosity

J2 Total PorosityK1 Total Porosity

K2 Total PorosityK3 Total Porosity

K4 Total Porosity

The error bars are derived from Monte Carlo simulations taking texture and sand composition variations into account

Resak-like model - WATER-BEARING RESERVOIRS

0

5

10

15

20

25

30

35

40

45

0510152025

Time (Ma)

Tota

l por

osity

%

D Total Porosity

E Total PorosityF Total Porosity

H1 Total PorosityH2 Total Porosity

I Total PorosityJ1 Total Porosity

J2 Total PorosityK1 Total Porosity

K2 Total PorosityK3 Total Porosity

K4 Total Porosity


SHALY SAND

CLEAN SAND

All runs in aquifer conditions

Moderate range = 10 to 25% Strong effect of compaction Limited quartz cement

Wide range : 7 to 30% Limited compaction Significant & variable quartz cement

TOTAL POROSITY a.a.f. DEPTH Slide 14

SHALY SAND

CLEAN SAND


Φ < 10 % at 2.5-3.0 km


0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

0 10 20 30 40 50

Total porosity %

Bur

ial D

epth

(m)

D Total PorosityE Total PorosityF Total PorosityH1 Total PorosityH2 Total PorosityI Total PorosityJ1 Total PorosityJ2 Total PorosityK1 Total PorosityK2 Total PorosityK3 Total PorosityK4 Total Porosity


K4 4720mK3 4370mK2 4020mK1 3670mJ2 3320mJ1 2970m

I 2569m H2 2147mH1 1709mF 1321mE 960mD 741m

0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

0 10 20 30 40 50

Bur

ial D

epth

(m)

Total porosity % Resak-like model - WATER-BEARING RESERVOIRSD Total Porosity

E Total PorosityF Total PorosityH1 Total PorosityH2 Total PorosityI Total PorosityJ1 Total PorosityJ2 Total PorosityK1 Total PorosityK2 Total PorosityK3 Total PorosityK4 Total Porosity

The error bars are derived f rom Monte Carlo simulations taking texture and sand composition variations into account

K4 4720mK3 4370mK2 4020mK1 3670mJ2 3320mJ1 2970m

I 2569m H2 2147mH1 1709mF 1321mE 960mD 741m

Φ < 10 % at 2.8-3.5 km

10%

10%

INTERGRANULAR POROSITY a.a.f. TIME Slide 15

SHALY SAND

CLEAN SAND

All runs in aquifer conditions Kenarong-like model - WATER-BEARING RESERVOIRS

0

5

10

15

20

25

30

35

40

45

0510152025

Time (Ma)

Inte

rgra

nula

r Por

osity

%

J1 Intergranular Porosity


K1 Intergranular Porosity





K4 4720mK3 4370mK2 4020mK1 3670mJ2 3320mJ1 2970m

I 2569m H2 2147mH1 1709mF 1321mE 960mD 741m


0

5

10

15

20

25

30

35

40

0510152025

Time (Ma)

Inte

rgra

nula

r Por

osity

%








K4 4720mK3 4370mK2 4020mK1 3670mJ2 3320mJ1 2970m

I 2569m H2 2147mH1 1709mF 1321mE 960mD 741m

Φ < 10 % in 3-9 my

Φ < 10 % in 7-15 my

10%

10%


0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

0 10 20 30 40 50

Intergranular Porosity %

Bur

ial D

epth

(m)








K4 4720mK3 4370mK2 4020mK1 3670mJ2 3320mJ1 2970m

I 2569m H2 2147mH1 1709mF 1321mE 960mD 741m


0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

0 5 10 15 20 25 30 35 40

Intergranular Porosity %

Bur

ial D

epth

(m)








K4 4720mK3 4370mK2 4020mK1 3670mJ2 3320mJ1 2970m

I 2569m H2 2147mH1 1709mF 1321mE 960mD 741m

INTERGRANULAR POROSITY a.a.f. DEPTH Slide 16

SHALY SAND

CLEAN SAND


Φ < 10 % at ~ 1.5 km

Φ < 10 % at ~ 2.5-3.0 km

Φ killed at ~ 3.0 km

Φ killed at ~ 3.5 km

10%

10%

POST-MORTEM of PROSPECT drilled in PM324 in 2012 Slide 17

Prospect

Top H Regional Depth Map

Lower Miocene at 1.5 to 3.3 km depth Sub-litharenites to sub-arkoses Some clay matrix (13% avg) TD (3.3km): T = 184oC P = 700 bar Non economical gas condensate

Sand Unit

Predicted total

porosity

Log porosity

Core plug porosity

Group H 21 % 25 % -

Group I 12 % 13 % 11%

Group J 7 % 11 % -

CONCLUSIONS & MESSAGES

Slide 18

Main results from Touchstone forward modeling:

Sand lithology is important but shaly vs clean is a trade off. Shaly sands more prone to compaction, clean sands more prone to quartz cement

In spite of high temperature, quartz cementation is rather limited due to limited duration in quartz window

Most favorable prospects to be looked for are : - sandy (arkosic) facies - showing long residence time at <2.5 km burial - charged with HC within 10 my after deposition

Refinement of the preliminary Touchstone model is needed, and is achievable provided better quality input data & basin modeling constraints.

Acknowledgements TOTAL EP France and Malaysia

for granting authorization to publish this work

THANK YOU for your attention

iptc-17945-abstract forward modeling of reservoir quality

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