EOR TECHNOLOGIES AND APPLICATIONS IN MALAYSIA - CCOP

EOR TECHNOLOGIES AND 

APPLICATIONS IN MALAYSIA 

The Petroleum Policy and Management (PPM) Project 

4 th Workshop of the Indonesia – Kutai Basin Case Study 

Jakarta, Indonesia 

13 – 17 June 2006 

Dr. Nasir Haji Darman 

Norhayati Bt Hashim 

1 

Presentation Outline 

• Introduction 

• Current Progress Updates and Status 

Dulang : Immiscible WAG 

Baronia : Immiscible Gas Injection 

West Lutong: Miscible Gas Injection 

Tapis: Miscible Gas Injection 

Tabu: Double Displacement 

• Issues and Challenges 

• Way Forward 

• Summary and Conclusions

Custodian of Malaysian Petroleum Resources 

Petroleum Management Unit 

(PMU) 

A distinctive resource owner and 

manager, maximizing value of 

Malaysia’s hydrocarbon resources 

Attract Attract exploration 

exploration 

investments 

investments 

Optimize Optimize Malaysian Malaysian 

E&P E&P Assets Assets 

Facilitates Facilitates 

development development & prod. prod. 

Monitor Monitor all all E&P E&P 

companies companies 

To fulfill our role and responsibilities, we must undertake 

and implement EOR initiatives 

PMU Key Business Focus Areas 

PMU objective to maximize the domestic long term value 

of reserves is done through 4 main levers 

Reserves addition 

100% replenishment ratio for crude 

and 70% for gas through exploration 

Reserves recovery 

Additional 33% replenishment 

ratio through IOR/EOR 

Reserves production 

Sustain 3% annual increase in 

production to meet demand 

Operational excellence 

Production enhancement and 

reliability improvement

EOR in Malaysia: Current Status 

We started off with conducting a screening in 2000 

& identified 1 Bstb (unrisked) EOR potential 

Our target is to add 520 MMstb of reserves from EOR by 2010 

Our progress so far… 

• Gas flood – 2 fields at full field WAG implementation, 1 on pilot 

• Chemical EOR – pilot for offshore AS flooding 

• Total of 11 projects at various stages (from lab study to full field) 

Some of our challenges… 

• PSC commitment – EOR project payback often after PSC expiry 

• Mindset – people view EOR as expensive and difficult 

• Gas vs. Oil – EOR will defer gas development (gas cap) 

EOR in Malaysia: What’s Next? 

Integrated CO 2 -EOR… 

• Why do it – Over 18 Tscf HC gas locked due to high CO 2 

– EOR competing for gas with sales gas/LNG 

–CO 2 perform better than natural gas 

• CO 2 supply – close to 5 Tscf in Peninsular Malaysia 

– over 24 Tscf in Sabah/Sarawak 

• EOR target – Project A: 9 fields (one area), 150 km from CO 2 source 

– Project B: 2 fields (one area), 140 km from CO 2 source 

• EOR process – immiscible and miscible 

• Status – Immiscible pilot started in June-06 

– Miscible pilot decision in final stages 

Our next step… 

• Phase 2 – Revisit EOR screening to identify new opportunities 

• Partnership – Strategic alliances with experience parties to make 

offshore EOR in Malaysia a reality

EOR in Malaysia: Our Roles to Make it Happen 

As a custodian of Malaysian Petroleum Resources, we have 

to manage and maximize our hydrocarbon assets 

We have to ensure 520 MMstb of reserves from EOR by 2010 a REALITY 

Re-negotiating our PSC in return for EOR implementation 

PSC renewal with longer period 

Better terms 

Tackling Triple Plus 

Leadership – Formal/Informal coaching, job attachments 

Mindset – support from the top, show positive results 

Institutional Capability – succession plan, EOR fraternity 

Revised procedure and guidelines 

EOR potential is assessed for every green field development 

IOR and EOR is integrated and not in silos 

Technology Improvement and R&D 

Supported by UTP, local universities 

Research Technology Division 

Overview of Malaysian Oil and Gas Industry 

• Oil was discovered in Malaysia in Miri, Sarawak in 1910. 

• Initially producing some 83 barrels per day, the petroleum industry in Malaysia has now 

grown into a multi-billion dollar business with oil production over 600,000 barrels per day 

while gas is being produced at 5 billion cubic-feet per day. 

• To date a total of 2,664,023 million line km seismic had been acquired and 1,100 

exploration wells (515 Appraisal and 585 Wildcat wells) had been drilled in Malaysia 

resulting in the discovery of a total of 134 oil fields and 178 gas fields.

Overview of Malaysian Oil and Gas Production 

4.500 

Malaysian Historical Crude Oil Trend 

0.300 

100.000 

Malaysian Historical Natural Gas Trend 

2.500 

Reserves, Bstb 

4.000 

3.500 

3.000 

2.500 

2.000 

1.500 

1.000 

0.500 

0.000 

0.250 

0.200 

0.150 

0.100 

0.050 

0.000 

Production, Bstb 

Reserves, Tscf 

90.000 

80.000 

70.000 

60.000 

50.000 

40.000 

30.000 

20.000 

10.000 

0.000 

2.000 

Production, Tscf 

1.500 

1.000 

0.500 

0.000 

1970 

1972 

1974 

1976 

1978 

1980 

1982 

1984 

1986 

1988 

1990 

1992 

1994 

1996 

1998 

2000 

2002 

2004 

1970 

1972 

1974 

1976 

1978 

1980 

1982 

1984 

1986 

1988 

1990 

1992 

1994 

1996 

1998 

2000 

2002 

2004 

Reserves 

Production 

Reserves 

Production 

• Malaysian oil reserves was in declining 

phase (from 1994 – 2002) 

• Through a concerted effort, our reserves 

return to an upward trend from 2003 

• Our target is to have a minimum of 1.33 

replacement ratio 

• At current rate of production, our 

reserves life is about 19 years 

• Current reserves is in plateau stage 

• Gas supply is critical to PGU and 

MLNG 

• Our target is to have a minimum of 0.7 

replacement ratio 

• At current production rate, our 

reserves life is 33 years 

EOR Potential 

• There is a substantial amount of oil reserves that can be achieved through 

IOR/EOR processes in the Malaysian oil fields. 

• Acknowledging the above, PETRONAS has initiated several initiatives to 

encourage the operators in Malaysia to look into EOR opportunities in their 

respective operating areas. 

Total STOIIP for Malaysian 

producing fields = 17 B stb 

Remaining oil 

(67%) 

EUR (33%) 

Total STOIIP 

17.0 B stb 

EUR 

5.62 B stb 

Remaining oil 

11.38 B stb 

Averaged RF 33% 

Source: ARPR 2005

To identify EOR potential, PETRONAS has conducted 

EOR screening study in year 2000 

• Based on the screening study, in Malaysian 

context, three EOR processes may be 

considered: 

Gas injection: miscible or immiscible in 

WAG or straight mode 

Chemical methods (surfactant, foam, 

polymer and gel), 

Microbial methods. 

CHEMICAL RECOVERY 

Recovery methods in this category may include surfactant, polymer and alkaline flooding. After a 

reservoir is conditioned by water preflush, specific chemicals are injected to reduce interfacial tension 

(help release oil) and /or improve mobility control (reduce channeling). This action is followed by 

injecting a driving fluid (water) to move the chemical and resulting oil bank to production wells. 

Mobility ratio is improved and flow through more permeable 

channels is reduced, resulting in increased volumetric sweep 

Single 5-Spot Pattern Shown) 

Injection 

Fluids 

Production 

Injection 

Well 

Pump 

Oil 

Injection 

Well 

Driving 

Fluid 

(Water) 

Fresh 

Water 

Buffer 

to 

Protect 

Polymer 

Solution 

For 

Mobility 

Control 

Additional 

Oil 

Recovery 

(Oil Bank) 

Preflush 

to 

Condition 

Reservoir 

MISCIBLE GAS FLOODING GAS FLOODING 

This method is a miscible displacement process applicable to many reservoirs. A gas slug 

followed by This alternate method water is a miscible and gas displacement injections (WAG) process is usually applicable the most to y man reservoirs. feasible method. 

A gas slug followed by alternate water and gas injections (WAG) 

Viscosity 

Viscosity 

of oil reduced 

of oil reduced 

providing 

providing 

more 

more 

efficient 

efficient 

miscible 

miscible 

displacement 

acement displ 

Produced Fluids (Oil, Gas and Water) 

Production well 

Separation and Storage Facilities 

Carbon Dioxide 

Water 

Injection well 

Injection 

Pump 

MICROBIAL FLOODING 

Recovery by this method utilizes the effect of microbial solutions on a reservoir. The reservoir is usually 

conditioned by a water preflush, then a solution of microorganisms and nutrients is injected. As this 

solution is pushed through the reservoir by drive water, it forms gases and surfactants that help to 

mobilise the oil. The resulting oil and product solution is then pumped out through production well. 

Single 5-Spot Pattern Shown) 

Microorganisms 

and Nutrients 

Production 

Injection 

Well 

Pump 

Produced Oil and 

Injection 

Products 

Well 

Drive 

water 

Gas 

Water 

Mis. 

Oil 

Additional 

Gas 

zone 

Bank 

Oil 

Recovery 

Driving 

Fluid 

(Water) 

Nutrients 

Microorganisms 

Microbial 

Products 

for 

Releasing 

Oil 

Oil and 

Products 

Preflush 

to 

Condition 

Reservoir 

Systematic approach has been developed to identify 

EOR potential in Malaysia 

• The study screened 31 reservoirs from 16 fields in the Peninsular Malaysia and 39 

reservoirs from 19 fields in East Malaysia. 

• Considering some practical limitation (such as gas source and reservoir heterogeneity), 37 

reservoirs were identified to be technically feasible for IOR/EOR processes. 

• Numerical simulation models (sector) were developed for the group which has the highest 

remaining oil-in-place and the highest recovery for the selected EOR process identified in 

the first-level screening. 

GO/NO 

GO 

Screening 

Prediction 

Runs 

Reality 

Check 

Screening 

PRIze 

Prediction 

Runs 

Sector Model 

Prediction 

Runs 

To identify suitable 

IOR processes for 

major producing oil 

fields in Malaysia 

Prediction run with Three (3) criteria set 

sensitivity analyses by IOR Team 

for 6 reservoirs 

Prediction run to 

estimate 

incremental oil 

recovery through 

IOR process 

Prediction run by 

sector model on the 

top six (6) reservoir

The amount of potential incremental recovery from 

these reservoirs is almost One (1) Billion barrels 

• Sixty percent (60%) of the total EOR potential in Malaysia reside in six reservoirs. 

Tapis Lower J 

200 

Total potential = 955 MMstb 

Number of reservoirs = 37 

Average size = 26MMstb 

Group 1 : 

570 MMSTB (60.4 %) 

Guntong Upper I 

150 

MMstb 

100 

50 

St Joseph B/G 

Tiong J – 20/21 

Guntong Lower I 

Dulang E-12/3 

(currently on pilot stage) 

Legend 

CO2 miscible 

Water Flood 

HC miscible 

Others* 

Other potential reservoirs: 

374 MMSTB (39.6 %) 

Dulang E-14 

(currently on pilot stage) 

0 

Producing Reservoirs 

The top 6 reservoirs have been identified as Group 1 

candidates (high remaining and incremental oil) 

* Includes Horizontal Wells, alkaline surfactant polymer flooding, surfactant polymer flooding. 

Source: PETRONAS 2000 EOR screening for Malaysia’s oil producing fields; CSS team analysis 












Phases for EOR implementation: 4 stages with 3 

decision gates review 

Stage 

Stage 

Activities 

Activities 

STAGE 1 

Screening 

study 

STAGE 2 

Detail study 

i.e. lab and 

simulation 

STAGE 3 

Pilot 

implementation 

STAGE 4 

Full field 

implementation 

Field and 

EOR process 

identification 

Preliminary 

economic 

assessment 

Pilot design 

and 

surveillance 

Economic 

assessment 

New data 

acquisition & 

processing 

Full field 

design & 

Economic 

Assessment 

Operation, 

maintenance 

and 

surveillance 

Decision 

Decision 

Gates 

Gates 

Gate 1 Gate 2 

Gate 3 

Viability 

Approval 

Concept 

Approval 

Project 

Sanction 

Yes Yes Yes 

No No No 

Alternative or Abandon 

Cost 

Cost 

Exposure 

Exposure 

Very low 

(Expense) 

Low 

(Expense) 

Med / High 

(Expense/capitalise) 

High 

(Capitalise) 

Currently we have 11 actively on-going EOR projects in 

Malaysia 

• At different level of maturity. Will discuss the progress of top 5 candidates 

Stage 3/4 

(Pilot or full field implementation) 

Stage 2 

(Detailed study) 

Stage 1 

(Preliminary / screening level) 

FIELD 

Dulang 

Tabu 

Baronia 

West Lutong 

FIELD 

Tapis 

Bokor 

CEOR 

Tiong/Kepong 

FIELD 

Baram 

Guntong 

St. Joseph 

PROCESS 

Immiscible WAG Injection 

Double Displacement 

Immiscible WAG Injection 

Miscible Gas Injection 

PROCESS 

Miscible WAG Injection 

Aquifer assisted WAG 

Chemical Injection 

Immiscible Gas Injection 

PROCESS 

WAG Injection 

Miscible WAG Injection 

Immiscible WAG Injection

Location of the 5 fields 

• Three at offshore Peninsular and two at offshore Sarawak 

THAILAND 

Dulang: 

• 130 km offshore Kerteh 

• Operator is PCSB 

Tabu: 


• Operator is EMEPMI 

Baronia: 

• 40 km offshore Lutong 


Kerteh 

KUALA LUMPUR 

Tapis: 


• Operator is EMEPMI 

SARAWAK 

BRUNEI 

SABAH 

West Lutong: 

• 12 km offshore Lutong 


Kerteh 

SINGAPORE 

KALIMANTAN 












Dulang field: Background Information 

Pilot Area … 

SCHEMATIC WELL LOCATION 

* B5 

* B16 

-1200 

*A10 

* A14 

N 

* A2 

-1250 

* A31 

S3 Block 

* A29 

• One of Malaysia’s major producing 

oilfield (OIIP =1119 MMstb and EUR 

= 328 MMstb) 

• East-West trending anticline 

structure dissected by numerous 

normal faults 

• Water depth of 76m and area ~11 km 

x 3.5 km 

Block S3 

• Pilot involves 3 producers and 3 

injectors 

Water injection started in 1996 due to falling pressures 

Re-injection of produced gas identified as cost effective EOR option 

Injected gas stream is having more than 50% CO2 

Pilot WAG at S3 block started in Nov-02 targeting E12/13/14 reservoirs 

Dulang Field: Immiscible WAG pilot strategy 

Implementation Strategy 

SCHEMATIC WELL LOCATION 

Main pilot – W AG & attic oil 

recovery 

* B5 

* B16 

-1200 

*A10 

WAG Inj. 

* A14 

Gas Inj. 

* A31 

* A2 

-1250 

* A29 

WAG Inj. 

Components of pilot in S3 block: 

1. WAG in non-water invaded area (E12/13/14) 

Injector: A10 

Producers: B5 and B16 

2. Gas injection (E12/13) 

Injector: A14 recomplete in E12/13 

Producer: A2 

3. WAG in water invaded area (E12/13/14) 

Injector: A29 

Producer: A2 

•WAG injection (4 MMscf /d gas and 3500 b/d water ) for cycles of 3 months each.

Dulang Field: Immiscible WAG pilot performance 

• Contributing WAG mechanisms 

drainage of ‘attic oil’ up-dip of the existing producers 

more efficient sweep of water flooded regions 

flooding of tighter reservoir intervals 

partial vaporization of the un-swept oil 

• Pilot performance 

Well A2L 

Well B5L 

Well B16 

10 BOPD 100 – 300 BOPD 

WCUT 95% 70% 

Pressure maintained 

350 BOPD 600 BOPD 

GOR 2000scf 1000scf 

1350 psia 1467 psia 

105 BOPD 300 BOPD 

GOR 4500scf 2200scf 

WCUT 80% 70% 

Dulang Field: Plan for full field implementation in 2007 

Based on pilot performance, results were scale-up to represent full field 

implementation. P50 of 18.5 MMstb of incremental reserves is expected. 

Acquisition of gas compressor and integration with FFR study is 

currently on-going 

P15 = 23 MMstb 

P50 = 18.5 MMstb 

P85 = 12 MMstb 

Infill Wells (2004 WP&B) 

Dulang Decline (2005/6 WP&B)











• Summary and Conclusions 

Baronia Field: Background Information 

• 3rd largest producing reservoir in 

the Baronia field. 

• Production started since 1972. 

• Initially under-saturated reservoir 

• Oil is 42 o API and 0.3 cP 

• Due to limited aquifer support, peripheral water injection commenced with 4 

horizontal injectors in 1994. 

• The structure is simple, internally unfaulted, low relief domal anticline. The 

reservoirs are highly continuous as demonstrated by good geological marker 

correlation.

Baronia Field: Immiscible gas pilot strategy 

 

 

 

Pilot Objective and Plan 

Test immiscible gas injection process 

Showcase for a large-scale immiscible gas injection in the BDO fields 

Location: Well BN-29 targeting RV2.1 reservoir 

• Gas will be injected 

from BN-29 at 5 

mmscf/d 

• Continue water 

injection from BN-58, 

horizontal injector 

• Pilot was designed to 

provide “least 

disturbance test” to the 

current oil production 

Baronia Field: Plan for pilot project in 2006 

Model predicted that immiscible gas injection of 5 MMscf/d with continued water 

injection from next well could yield 2.7 MMstb incremental recovery. 

Pilot FDP has been approved by PETRONAS and flowlines modification 

is currently underway to convert BN-29 well to become gas injector 

Baronia RV2 immiscible gas injection pilot will be interpreted together with 

West Lutong miscible pilot (described later) to come out with regional EOR 

implementation strategy at Baram Delta 

20% 

Incremental Recovery as %STOIIP 

18% 

16% 

14% 

12% 

10% 

8% 

6% 

4% 

2% 

(W Lutong) 

Miscible 

Near Miscible 

Immiscible 

(Baronia) 

0% 

-2% 

0% 20% 40% 60% 80% 100% 120% 140% 160% 180% 200% 

Cumulative Injection Since Start of Gas Injection as %HCPV












West Lutong Field: Background Information 

• One of the oldest producing field in Malaysia 

• KL and MN reservoirs contribute > 70% of 

the total production 

• 1/3 of the MN commingled modeled as a 

single unit. STOIIP = 110 MMstb 

• Pilot to test miscible gas injection in Baram Delta fields 

• MMP at or near current reservoir pressure. Strong aquifer.

West Lutong Field: Miscible gas pilot strategy 

Pilot 

Injector 

(New) 

Logging, 

Observation Well 

(Fiberglass 

Casing, Slimhole) 

Capture 

Producer 

PILOT PLAN 

1 injector and 1 observation 

(100 feet apart) 

M 

Perforations 

Barge mounted CO2 

generator supplying 2 

MMscf/d high purity CO 2 

3 months at 1500 psi 

injection pressure 

N 

1 st injection anticipated early 

2007 

100 ft 

*Note: Well distances are notional 

1,100 ft 

West Lutong Field: Plan for pilot project in 2007 

PILOT OBJECTIVE 

Determine remaining oil saturation Vertical sweep efficiency 

Areal sweep efficiency 

Minimum miscibility pressure 

Injectivity and need for WAG injection 

“The West Lutong pilot, if implemented, will become the first miscible 

pilot in Malaysia. If successful, the miscible process can give 

an incremental of up to 165 MMstb for the BDO fields.” 

Miscible 

Immiscible 

165 

MMstb 

91 

MMstb 

0 50 100 150 200 

Incremental oil (mmstb) 

West Lutong 

Baram 

Baronia 

Betty 

Bakau 

Bokor 

Tukau 

Siwa 

Both pilots at Baronia 

and West Lutong are 

planned to confirm 

256 mmstb 

incremental oil at 

Baram Delta region 

(miscible and 

immiscible 

processes)












Tapis Field: Background Information 

TAPIS EAST-FAULT BLOCK STRUCTURE MAP 

• Water depth 64 meters 

• Discovered in 1969 

EFB 

Pre-Production 

GOC : -1550 m 

OWC : -2050 m 

• Five platforms 

• 90 development wells 

F-02 

F-06 

F-04 

CI = 50m 

• Current focus is on the east 

fault block of lower J 

reservoirs 

Small gascap is present in the fault block 

Lower J unit have contributed some 40% of the total Tapis production.

Tapis Field: Miscible gas study work flow 

Tapis EOR study workflow 

Tapis Field: Miscible gas study 

 

 

 

 

Lower J Unit was selected due to… 

Potential recovery of bypassed and residual oil from mature waterflood 

Large remaining oil remaining in place 

Existing water & gas injection facilities, existing well patterns 

New geologic model and a history matched simulation model available 

Miscible 

Separator gas 

LPG enrichment 

Process evaluated 

Immiscible 

CO 2 

“The immiscible floods yielded an incremental recovery between 4-7% 

whereas miscible floods gave a higher recovery between 10-13%.”












Tabu Field: Background Information 

• Oval-shaped east-west 

trending anticline 

• Area = 26 km 2 

• Water depth = 64 meters 

• Two major north-south 

trending normal faults 

• Discovered in 1978 

• Developed in 1986 

Study focused on West Fault Block (WFB) in the Upper I reservoirs 

Double displacement process (DDP) is currently being tested

Tabu Field: The double displacement process 

• Potential recovery of by-passed oil downdip of high 

GOR wells by converting alternate wells along 

periphery of oil rim to water injectors 

• The up-dip injector forces the gas cap towards 

southwest, countering the aquifer influx and 

increasing future oil from nearby wells. 

• Cost of flowlines, well restoration and surveillance is 

relatively minimal 

• Prediction runs showed that DDP for the Tabu WFB 

Upper I reservoirs alone will give an estimated 

incremental of 1.8 MMstb 

• Field works are currently on-going 












Operating EOR in offshore environment is technically 

challenging 

• Only about 9% of world wide EOR application is in offshore environment. On the other 

hand, all of our producing fields are offshore. 

• Some of the most common problem associated with offshore operation 

Large well spacing 

Limited space at the surface 

World-wide EOR experiences 

Well spacing for Group 1 reservoirs 

World-wide EOR 

applications (%) 

100 

75 

50 

25 

Well spacing for Group 1 EOR candidates (feet) 

2500 

2000 

1500 

1000 

500 

Well spacing for Group 1 reservoirs is suitable for gas 

injection EOR but not chemical 

Average well spacing for 

successful gas EOR project 

Range of successul chemical EOR (330 - 466) 

0 

Offshore 

Onshore 

Source=OGJ 2002 

0 

Min Average Max 

On average, 68% of the 157 existing platforms installed 

in Malaysia are more than 20 years old 

• Gas injection pipeline, especially with CO2 handling capability, does not exist. Major 

infrastructure development is needed (major investment). 

• Some of the fields are not reaching the MMP even if 100% purity CO2 is injected. Major 

repressurization project for the reservoir is needed before MMP is reached. 

• 68% or 157 platforms had been in-placed more than 20 years. 

70 

33% < 20 years 68% >20 years 

60 

No. of platform 

50 

40 

30 

20 

10 

0 

5 10 15 20 25 30 35 

Age of platform

Operating EOR in offshore environment is 

commercially challenging 

• For gas flooding (such as CO 2 

injection), the average total cost per barrel is around 

US$ 12 – 20, which, compared to average unit technical cost in Malaysia, is relatively 

high. 

World wide EOR cost database 

Process 

Cost of Incremental Oil (US$/bbl) 

Injectant Only 

Total Process 

Thermal 

Steam 

Purchased Fuel 

3 – 5 

4 – 6 

5 – 7 

7 - 10 

Gas 

CO2 

5 – 10 

12 - 20 

Chemical 

Surfactant (Micellar) 

Alkaline 

Surfactant/Alkaline/Polymer 

Polymer 

10 – 20 

~ 7 

2 – 7 

1 – 5 

20 – 30 

~ 19 

10 – 17 

~ 2 - 7 

Source=SPE 24142 

Timing is critical to realise the EOR potential 

• A clear and transparent work process must be in place to ensure that all of the 

requirements for the project assessment are met. 

• Long timing leads to unfavorable economics especially to the Contractors. Cut the time 

required to reach full field application, without cutting any corners … 

EOR Candidate 

Industry 

standard 

(e.g. Jay/Little Escambia) 

1 

Reservoir Management strategies 

based on historical information together 

with experimental and simulation studies 

2 – 3 

years 

Large field scale 

WAG applications 

Surveillance 

of projects 

Field expansions without 

a complete interpretation 

of pilot projects 

(e.g. Prudhoe Bay) 

Successful 

projects 

3 

2 

Pilot projects 

Pilot Monitoring 

Pilot Evaluation 

3 – 5 

years 

Source: SPE 50645, 1998 

Optimization programs

Current mindset and behaviour prohibits EOR potential 

• EOR is always associated with uneconomic projects and very difficult to implement, even 

without study being done. 

Most people in the industry have a disaster mentality 

about EOR 

EOR Failure Disaster 

“The most important reservoir is the reservoir 

between our ears” 

Dr. John Doran, CEO – ROC Oil Company Ltd 



• EOR Motivations and Focus 










Way Forward 

Solution 1 

Solution 1 

Solution 2 

Solution 2 

Solution 3 

Solution 3 

Solution 4 

Solution 4 

Solution 5 

Solution 5 

Management support 

- clear directions 

- conducive environment for EOR 

- Strategic and forward thinking 

Learning from pilot & other projects worldwide 

- balancing risk and benefit 

- Take some calculated risks 

- effective networking and collaboration effort 

Starting early 

- EOR need to be considered even during FDP 

submission for green fields 

Synergy in high CO2 gas field development 

- long term abundant supply 

- facilities sharing by integration 

Win-win situation with PS Contractor 

- attractive PSC terms 

- work commitments 

- Focus on REWARD and not COST 



• EOR Motivations and Focus 










Summary and Conclusions 

• There is a substantial amount of oil reserves that can be achieved through EOR 

process in the Malaysian oil fields. 

• Acknowledging the above, PETRONAS has initiated several initiatives to 

encourage the operators in Malaysia to look into EOR opportunities in their 

respective operating areas. 

• Previously, there were little detailed studies have been conducted to firm up 

these potentials and monetised them into a full-scale EOR projects. 

• Among the main challenges are the operating environment (offshore), maturing 

assets which require facilities upgrading, limited detailed assessments, and 

lack of capability were identified. 

• In order to meet these challenges, all parties will need to have the right mindset 

and behaviour towards realising EOR as a real project to increase value in the 

business. 

Thank You For Your Attention

EOR TECHNOLOGIES AND APPLICATIONS IN MALAYSIA - CCOP

Create successful ePaper yourself

Delete template?

Save as template?