www.partex-oilgas.com Maria Teresa Ribeiro, E&P Manager, Partex Oil and Gas

DEVELOPMENT OF A

LOW PRODUCTIVITY FIELD IN

KAZAKHSTAN

OUTLINE

Partex in The World

Partex Technology Areas

Dunga Field – Onshore Kazakhstan

General Information

Project Challenges

Technology Implementation

Reservoir Characterization & Modelling

Development Strategy

Well Design & Stimulation

Surface Facilities Overview

PARTEX – GEOGRAPHICAL AREAS

Operations in Oil & Gas Upstream Activities

Participations in Concessions and JV Worldwide

Exploration, Development, Production and Sales

Organization by Geographical Areas

MIDDLE EAST

PARTEX OIL AND GAS (HOLDINGS)

CORPORATION

PMOS PARTEX SERVICES

PORTUGAL

KAZAKHSTAN

PARTEX (KAZAKHSTAN) CORP

(DUNGA) – onshore Oil production

ALGERIA

PARTEX (ALGERIA) CORPORATION

(AHNET) – tight Gas development

ANGOLA

PARTEX (ANGOLA) CORP

(BLOCK 17/06) – deep offshore pre-

development

BRAZIL

PARTEX (BRAZIL) CORPORATION

(COLIBRI) - onshore Oil production

(CARDEAL) – onshore Oil production

(BM-S-10) – deep offshore expl

(SEAL-9) – offhore expl

OMAN

PARTEX (OMAN) CORPORATION

(PDO) – onshore Oil production

(OLNG/QLNG) – LNG production

(MUKHAIZNA) – heavy Oil production

UAE

PARTICIPATIONS & EXPLORATIONS

CORPORATION

(ADCO) - onshore Oil production

PARTEX GAS CORPORATION

(GASCO) – LPG & Nafta production

PORTUGAL

PARTEX (IBERIA) CORP

(PENICHE ) – deep offshore expl

(ALGARVE) – Gas offshore expl

PARTEX - PARTNERS

January 2013

KAZAKHSTAN (Dunga)

Gov. of Kazakhstan

Maersk

Oman Oil Co.

OMAN (PDO)

Gov. of Oman

Shell

Total

OMAN (Mukhaizna)

Government of Oman

OXY

Oman Oil Co.

Liwa Energy

Shell

Total

OMAN (OLNG)

Government of Oman

Shell

Total

Korea LNG

Mitsui

Mitsubishi

Itochu

UAE (ADCO) ADNOC BP ExxonMobil Total Shell

UAE (GASCO) • ADNOC • Shell • Total

BRAZIL

Petrobras

British Gas (in BMS-10)

ANGOLA (Block 17/06)

Sonangol P&P

Total (TEPA)

SOMOIL

Falcon Oil; SSI; Acrep

PORTUGAL

Petrobras/ GALP (Peniche)

Repsol (Algarve, Peniche)

ARGELIA

Sonatrach

Total

GEOLOGICAL AND

GEOPHYSICAL MODELLING

• Seismic Inversion

• Simulations of rock facies

constrained to Seismic data

RESERVOIR

CHARACTERIZATION

• Geostatistics

• Multidimensional Analysis

• Stochastic Simulation

FRACTURED RESERVOIRS

• Fractures Simulation

• Data Integration

• Upscaling

• Incorporation of

Dynamic Data

COMPOSITIONAL

SIMULATION

• No. of Components

• Equation of State

• Model Definition / Work

ASSET INTEGRITY

MANAGEMENT

• Inspection & Corrosion

• Quality Control

• Material Selection

ADVANCED PVT

• Fluid Sampling

• Data Validation

• Lab Studies

RESERVOIR SIMULATION

• Model Definition

• Integration of Lab Data

• Integration of Dynamic Data

• Automatic History Match

• Prediction Scenarios

OPERATIONS

• Crude Degasser Technology

• Drilling

• Production Technology

• Artificial Lift

• Gas Plants

• Water Bacterial Treatment

PARTEX

TECHNOLOGY

AREAS

EOR

• Gas Injection Projects

• Microbial Processes - MEOR

R&D Projects

DUNGA FIELD – ONSHORE KAZAKHSTAN

PSA until 2024 (Started 1998)

Maersk Oil KZ 60%

OOCEP 20%

Partex 20%

DUNGA PROJECT – PARTNERSHIP

DUNGA PROJECT - A CHALLENGE

Complex Low Productivity Reservoir

requiring a

Phased Development Approach trough

Pilot Projects

to better define the

Field Development Strategy

Licence effective date 29 Nov-1996

Production 25 Years

Partex become Operator (50%) Dez-1998

First well (DGA-26) spud 6 Nov-1998

CGF start up 20 Jan-2000

First Oil exported Mar- 2000

Farm in- Maersk become Operator (60%) 9 Ago-2001

FFD II for 198 vertical wells submitted to CCED Nov-2010

FFD II 1st Oil Dec-2012

BACKGROUND

Oil export route

Several alternatives, all expensive (~$10/bbl)

No quality bank, i.e. downgrading of oil

Water management (re-injection & sea water)

Gas utilization

Gas sales vs. power generation

LPG injection vs. LPG sales

Field Development Plan

Complex reservoir

Complex approval process

Reservoir management

Future development phases, EOR?

Facilities and infrastructure

Local content, access to local contractors, heavy bureaucracy

Access to land

PROJECT CHALLENGES

Reservoir Characterization

Complex deltaic geology, low permeability, shale laminations

Fluid Characterization

Sweet oil, good API (~40), strong paraffinic nature (pour point ~25º)

Well Design and Stimulation

Vertical single frac, slanted, horizontal multi-frac, open hole fishbone

horizontal

Hydraulic Fracturing

Design optimization, operational efficiency

Field Development Planning

Phased and optimized

Full integration of data acquisition and reservoir studies

EOR

LPG injection, future options

TECHNOLOGY IMPLEMENTATION

DUNGA FIELD

RESERVOIR CHARACTERIZATION

& MODELLING

Data Input Data Input & QC & QC

Data Input Data Input & QC & QC

Structural

Modeling 3d Grid Definition

Facies Modeling

Facies Modeling

Modeling

- - Simulation Simulation

Volumetrics Volumetrics Volumetrics Volumetrics

Data Analysis Data Analysis

Uncertainty Assessment Uncertainty Assessment Ranking Ranking

Uncertainty Assessment Uncertainty Assessment Ranking Ranking

Model Model Upscalling Upscalling

(Muhairi et al., ADIPEC 2006)

Aptian

Aptian A Aptian B

DEPOSITIONAL ENVIRONMENT

Porosity

Permeability

Facies

APTIAN

GEOLOGICAL MODELLING

2000 x 2000 1000 x 1000

200 x 200 500 x 500

Unit: A1 (Layer 60)

FACIES MODELS

2000 x 2000 1000 x 1000

200 x 200 500 x 500

Unit: A1 (Layer 60)

POROSITY MODELS

• West / East sectors of 1km2 extracted for dynamic simulation

• 43 layers of ~2 ft thickness. Gross thickness 100ft (Top A0-Base B2)

• cells 13x13m for proper induced fracture modeling

• 5 spot pattern with vertical wells (central well is injector or producer)

Porosity

L

Simulation Study for Sensitivity

Analysis:

• Well spacing

• Subsurface realizations

• Height above FWL

• Rock properties

• Well control (rate, fracture

size, injection)

DYNAMIC MODELLING – SECTOR MODELS

Sandy Dolomite

Sandy Clastic Dolomite

Silt-Sandy Dolomite

1

2

3

4

5

PI Summer Project:

M. Tarik, Aug-2011

CARBONATE

PI Summer Project:

M. Tarik, Aug-2011

ROCK TYPING

1960 1950 2000 1990 1980 1970 2010 2020

Well log and 2D

seismic data

• Integrated

reservoir management

• Geosteering and wells

trajectory optimization

• Advance depth imaging

and attribute analysis

• 4D seismic / monitoring

3D seismic, reservoir

characterization

and simulation

- P

rod

ucti

vit

y g

ain

+

PAVING THE WAY TO INCREASE RECOVERY

RESERVOIR CHARACTERIZATION WORKFLOW

Reservoir Characterization

& Modeling

Log Data

Core Data

Fluids &

Contacts

Uncertainty Analysis

& STOIIP

Analogues &

Depositional Models

Seismic

Structure

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231000 232000 233000 234000 235000 236000 237000 238000 239000 240000 241000 242000

231000 232000 233000 234000 235000 236000 237000 238000 239000 240000 241000 242000

2665000

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2670000

2671000

-10900-10880-10860-10840-10820-10800-10780-10760-10740-10720-10700-10680-10660-10640-10620-10600-10580-10560-10540-10520-10500-10480-10460

Depth

0 500 1000 1500 2000 2500Horizon name

THAMAMA_SUBZONE_FIIrfan_Hendrawan 22/08/2006 NEB_MASTER.pet

P10 P50

P90

RRT Pore Throat Distribution

0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1.0

0.001 0.01 0.1 1 10 100

Pore Throat Radius, microns

Mer

cury

Sat

ura

tio

n, f

ract

ion

R35

Increase Grain Size

RRT 1RRT 2RRT 3RRT 4RRT 5

Increase Sweep Efficiency

RRT

Hg-Injection Dataset

0.01

0.1

1

10

100

0 5 10 15 20 25 30 35

Core , %

Co

re k

h,

mD

Log R35 = 0.255 + 0.565Logkh - 0.523Log(Pittman, 1992)

0.35 m

Pore Throat Size @ 35%SHg

0.22 m

0.10 m

RRT 1RRT 2RRT 3RRT 4RRT 5

RESERVOIR MODELLING

Solution

• Integrate Geology, Petrophysics & Seismic

• Detailed description of the reservoir

• Build several reservoir realizations/scenarios

• Dynamic evaluation/ simulation

Results

• Better quality of dynamic simulations

• Fit-for-purpose reservoir realizations/scenarios

• Directly applicable to FDP

(Bizarro et al., 2010)

Water Injection

makes a barrier

to gas

expansion

Free gas was sampled in crestal well

Gas composition resembles gas from

a Lower reservoir

Gas cap expanded due to lack of

pressure support and continuous gas

raising from Lower Aptian, probably

behind casing due to poor cementation

HIGH GOR WELLS

Cement bond log shows poor

cementation all the way down until the 7”

Water influx from the Albian aquifer

above

HIGH WATER CUT WELLS

Data Acquisition in Pumping Wells Miljenko Cimic, SPE, TNK-BP Management and Laura Soares, Partex Oil & Gas SPE 101846 Publication

DUNGA FIELD

WELL DESIGN & STIMULATION

Previous approach

DGA-50H and DGA-52H

New approach

DGA-53H

LINER TYPE

Pressure

400 psi

Formation

Pressure

Profile

Planned fracture Planned fracture Planned fracture

Nozzle

Executed fracture

Aptian B

Aptian A

Conventional

Method

SurgiFrac Technique

WELL STIMULATION – FRACCING

Characteristics:

Vertical well with a Conventional Proppant Hydraulic fracturing and an initial post-fracture production rate

of 1500 bbl/d and 10% Wcut , against a pre-fracture production rate of 120 bbl/d and 5% Wcut.

WELL STIMULATION – DGA-27V

Fracture half length

(A+B)

Fracture Growth Direction

0

100

200

300

400

500

600

VE

R C

onventional (2

7D

V)

VE

R C

onventional (4

3V

)

VE

R C

onventional (4

5V

)

VE

R C

onventional (4

9V

)

VE

R C

onventional (4

6V

)

VE

R C

onventional (4

2V

)

VE

R C

onventional (4

4V

)

VE

R C

onventional (4

8V

)

VE

R C

onventional (4

7V

)

HO

R p

si (3

4H

)

VE

R s

urg

ifra

c (

40V

)

HO

R s

urg

ifra

c (

41H

)

HO

R s

urg

ifra

c (

50H

)

HO

R s

urg

ifra

c (

53H

)

HO

R s

urg

ifra

c (

54H

)

HO

R s

urg

ifra

c (

39H

)

DE

V s

urg

ifra

c (

36D

)

HO

R s

urg

ifra

c (

51H

)

HO

R s

urg

ifra

c (

52H

)

DE

V S

urg

ifra

c (

28D

H)

HO

R s

urg

ifra

c (

38H

)

Avera

ge l

iqu

id p

rod

rate

(fi

rst

100 d

ays)

per

fractu

re [

stb

/d]

VER Conventional (27DV)

VER Conventional (43V)

VER Conventional (45V)

VER Conventional (49V)

VER Conventional (46V)

VER Conventional (42V)

VER Conventional (44V)

VER Conventional (48V)

VER Conventional (47V)

HOR psi (34H)

VER surgifrac (40V)

HOR surgifrac (41H)

HOR surgifrac (50H)

HOR surgifrac (53H)

HOR surgifrac (54H)

HOR surgifrac (39H)

DEV surgifrac (36D)

HOR surgifrac (51H)

HOR surgifrac (52H)

DEV Surgifrac (28DH)

HOR surgifrac (38H)

Green: vertical well

Red: Horizontal well

0

500

1000

1500

2000

2500

0 500 1000 1500 2000 2500 3000 3500

Oil

Rat

e (b

bl/

d)

Days

Vertical and Horizontal Production Comparison

Vertical Well 1 Horz Well 2 Horz Well 3

0 $

2,000,000 $

4,000,000 $

6,000,000 $

8,000,000 $

10,000,000 $

12,000,000 $

14,000,000 $

16,000,000 $

1V 2V 3V 4V 5V 6V 7V 8V 9V 10V 11V 1H 2H 3H 4H 5H 6H 7H 8H 9H 10H

Well Drilling Cost vs Current Production

195

bb

l/d

101

bb

l/d

204

bb

l/d

547

bb

l/d

299

bb

l/d

91 b

bl/

d

358

bb

l/d

51 b

bl/

d

481

bb

l/d

357

bb

l/d

267

bb

l/d

1321

bb

l/d

660

bb

l/d

376

bb

l/d

535

bb

l/d

548

bb

l/d

450

bb

l/d

470

bb

l/d

624

bb

l/d

Inje

cto

r

157

bb

l/d

Well stimulation by fraccing is fundamental to

develop this reservoir

Long reach horizontal wells with multifracs

are not efficient in this type of reservoir

Selected Development strategy:

- Vertical wells with a single frac

Vertical well

Horizontal well

Average production per fracture

VERTIVAL vs. HORZONTAL WELLS

From the review of operations, fracture stimulation data, production performance and

cost, vertical wells are preferable to enhance the inflow from the reservoir to the wells

after sand hydraulic fracture stimulation

Although a low k reservoir with the presence of local baffles, pressure communication

exists over larger horizontal distances and shows also good injectivity

3D sector models were cut from the static model to conduct a sensitivity analysis for

Phase II development: proximity of FWL, fracture stimulation, reservoir continuity,

water injection

Pressure support with Water Injection using all produced water and surplus needed

from Caspian Sea

Results from LPG injection show that it can be equally good or better for pressure

support (further evaluation needed)

Infrastructure and Expansion of the process facilities with full use of associated gas

FIELD DEVELOPMENT - CONCLUSIONS

EXISTING FACILITIES

WELL TEST SEPARATORS

1st & 2nd STAGE SEPARATORS

H 401 A/B: Designed to heat the production before being sent to the separation train H 4021C/D: Designed to heat the oil in the storage tanks via circulation pumps. H 401A was replaced to new one PBT-1.6M.

Oil heater H401 B Oil heaters H401 C/D

HEATERS SYSTEM

Cleaning of old inlet production separator

Significant amount of solids and paraffins

Some corrosion presence inside vessel

Work ongoing

Next inspection of V-211,new inlet production separator

Sludge treatment facilities is part of Dunga Phase II

Inspection of Separator V-201

SEPARATORS INSPECTION

Water settlers V-602 & V-603 Water transfer pumps P205A/B Pumps P606 A/B for transferring separated

oil from V-603 to V-201.

Water quality for injection: - Total oil in water - Total solids

Dunga Daily Production Summary Report 12Mar2012

?

PRODUCED WATER TREATMENT

DGU start up on Oct2009

Associated gas in Dunga is very rich and is split in three streams:

Heavy fraction

Mid fraction

Light fraction

Achieved by compression and then flashing the gas.

DUNGA GAS UNIT

DGU process gas sales to pipeline specification and,

Delivering LPG stream to reinjection wells. Gas treatment capacity, 10MMscfd (300 000m3) Glicol Package System: (In glycol dehydration process, a liquid desiccant dehydrator serves to absorb water from

the gas stream).

Joule-Thompson effect

DUNGA GAS UNIT

Oil Storage Tanks T101 & T201

STORAGE TANKS

CGF to KTO pipeline (Kalamkas- Karazhambas-Aktau DN 700 line): 6” line, 18.2 km long heated and insulated fiberglass pipeline Pig system (ball valve -launcher/receive); Ameron fibreglass pipe CENTRON SPH 1000, characteristics: - Pipe external diameter is 165.6 mm - Wall thickness 5.3 mm - Design pressure: 68.9 bar @38ºC, 65.5 bar @ 52ºC;

Polyurethane insulation (50mm) with polyethylene external protection, heated via a skin effect tracing system; Difference in elevation from Dunga to KTO pipeline injection point is 75m.

Pipeline starting point with ball launcher valves and

heating container

OIL EXPORT PIPELINE

EXPORT ROUTE

Obrigada