rejuvenation of mature hydrocarbon assets thru application

http://www.3dosglobalenergy.com/

Rejuvenation of Mature Hydrocarbon

Assets thru Application of Technology and

Reservoir Management

Syed M. Tariq

Executive Vice President, Subsurface

3DOs Global Energy LLC, Houston, Texas

September 15, 2017

Jakarta, Indonesia

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2

Lifecycle of an Hydrocarbon Asset


Our Subsurface Experience

At 3DOs, we have expertise in revitalizing mature hydrocarbon assets in a cost effective manner:

Global network and database

Competent, qualified team (RE, PE, Geo)

High quality analytical/numerical tools

Integrated workflows

Technology

Our team can undertake evaluation of mature assets, generate opportunities, conduct technical studies and execute projects to maximize value for our clients

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Production Enhancement of Mature Assets: Let’s Get the Most Out of Existing Wells

• An effective way to increase production is by looking where oil and gas has already been found and produced. Existing wells with gaps in performance are the target of a focused and aggressive initiative to enhance production

• The objective of production enhancement is to identify and close gaps between current well output and productive potential.

• Closing the gaps between current output and productive capacity is an opportunity to quickly enhance production and improve recovery. 3DOs team has effective and proven methodology to tap into potential productivity and increase asset value

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Production Enhancement for Mature Assets

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The majority of production problems in mature fields in North America are due to reservoir and completion issues


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Reservoir Management & Surveillance The key to Field Production Optimization

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3

What is Reservoir Management?

• Reservoir Management is the dynamic process of

formulating and implementing a strategy for developing

and depleting a hydrocarbon reservoir. The objective is to

maximize the economic value of the reservoir.

• “Integrated” Reservoir Management means the synthesis

of geoscience, engineering and other functional data and

interpretation into a model for evaluating Reservoir

Management strategies

• Systematic Reservoir Management and Surveillance

leads to opportunities for enhanced production volumes

and recovery


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Focus: Reservoir surveillance, Wellbore utilization, Opportunity Generation, EOR, Abandonment


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13


Depletion Plan Evolves

W

W G

O

W

Well Design

2. Monitoring / Surveillance

Well Locations

3. Optimization / Enhancements

Infill Wells or Workovers

Facility Debottlenecking

Modifications to Production/Injection Rates

Facilities

1. Development Plan

Depletion approach (primary or secondary)

Wells and their Location

Production Facilities

4. Redevelopment / IOR/EOR Schemes


Volume Growth by Opportunity Generation

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3DOs Opportunity Generation workflow is a process by which significant value

is created in a Mature Asset by recognizing gaps and taking appropriate action


Case Study: Asset Optimization

• Major oil reservoir with associated gas cap; discovered 1940

– OOIP ~ 1.4 GBO (ex Asphalt); OGCGIP ~ .4 TCF

– Overall field recovery to date ~ 60%

o Up to 80% RF with 100% gravity stable gas drive/very low Sorg

• High quality fluvial Woodbine sandstones

– Dexter (main oil zone) and Lewisville (fuel gas source)

HAWKINS HAWKINS HAWKINS HAWKINS HAWKINS HAWKINS HAWKINS HAWKINS

Wood County, TX Original Fluid istribution

Gas

Oil

Water


Double Displacement Process (DDP)

Water-Invaded Oil Column

Gas

Asphalt

Oil

Water

Shut In

Shut In

Gas

Injector

Oil Producer

DISCOVERY

CONDITIONS

1940

PROJECT

ULTIMATE

CONDITIONS

Shut In Shut In

Shut In

Gas

Injector

Gas

Injector

Oil Producer

Water

Withdrawal

Well

Oil Producer

(Ultimate

Drainage)

CURRENT

CONDITIONS

1993

CONDITIONS

– Purpose of DDP: recover oil bypassed by the original water drive mechanism via gas displacement & gravity drainage.

– Key to success of the DDP process is achieving oil column movement at a desired rate of 10 to 15 / years.

– Column movement is achieved by bailing water to provide accommodation for expanding gas cap by N2 injection.


Hawkins DDP Performance

Hawkins Cumulative Oil Production

0

10

20

1990

1995

2000

2005

MB

O

• Dark green area provides estimate of performance without DDP

• Incremental production and reserves shown in light green.

• Incremental recovery estimate of ~20 MBO from 1990-2010 (~ 1.5% of total OOIP)

Process will continue during remaining field life

• “Pure” incremental recovery +2 to 3% (25 to 40 MBO)

Project benefit significantly greater (more than 2 times EOR increment)

30 6

40

50

60

Hawkins Oil Production

0

2

4

8

10

12

14

1990

1995

2000

2005

kb

od

Base Base

DDP

DDP

Case Study: Asset Optimization

Pressure maintenance should be evaluated to prevent gas

cap shrinkage, pressure depletion or improve recovery.

GAS INJECTION

STRONG NATURAL

WATER DRIVE

MODERATE NATURAL

WATER DRIVE

MAXIMUM FLUID

WITHDRAWALS

WATER

INJECTION

ORIGINAL GAS - OIL CONTACT

ORIGINAL OIL - WATER CONTACT

GAS - OIL

CONTACTS

STABLE

Webster Field, Texas. Water injection in WFB

supplements water drive. Eliminates pressure

difference between FBs & gas migration. Both fault blocks

produce by efficient

water drive.

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Example: Opportunity Generation

Evaluate horizontal or extended reach drilling.

Recover uneconomic reserves.

Improve profitability through lower development costs.

Extend life of field -- less gas & water production. Additional recovery due to adverse reservoir description.

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3DOs Experts have Experience in Field Optimization Globally

• Development Optimization • In-Place estimate using material balance history match

• Artificial lift design and optimization

• Surface facility design spec and optimization

• Completion performance comparisons and selection

• Field development option evaluation

• De-bottlenecking

• Tubing flow estimate and optimization

• Surveillance

• Diagnostics of problems

• Faster well and field performance prediction

• Forecasting

• Depletion method evaluation

• Forecasts for planning and budgeting

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Improved Oil Recovery / Enhanced Oil Recovery

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What is “IOR” and “EOR”?

• Improved Oil Recovery (IOR) includes EOR as well as processes

such as waterflooding, artificial lift, gas cycling, infill drilling, smart

wells, completion/stimulation, etc

• Beyond primary depletion, basic reservoir management, surveillance

and opportunity generation

• Enhanced Oil Recovery processes are those that improve recovery

from injection of non-native fluids or energy deep into the reservoir

with the aim of altering the physical mechanism of recovery.

• Includes non-HC gases, enriched gases, chemicals, heat, bacteria

• Other terms : ILOR, MEOR, CEOR, XOR etc

• IOR/EOR and unconventional recovery processes.

• e.g. shale oil, heavy oil mining, tight gas


Limitations of Primary Recovery

40

20

0 0 10 20 30 40 50 60

Recovery Efficiency, % OOIP Resv.

Pre

ssu

re, %

Ori

g.

Pre

ssu

re

• Around 1/3 to 2/3 of OOIP remains in a reservoir when production

under natural drive mechanisms reaches abandonment.

100

80 Water Influx

60

Gravity Drainage

Gas Cap Expansion

Liquid Rock Expansion

Solution Gas Drive


Secondary Recovery: Waterflooding

• Approach: • “mimic” natural water drive – maintain

reservoir pressure and displace oil with water

• Waterflooding is regularly practiced due to low cost and wide availability of water as an injectant

• Maximum ultimate recovery is at Sorw and when Ev = 1

• Economic recovery limit is less

Oil Water

Water-Oil kr - Primary Imbibition

0.1

0

0.2

0.3

0.5

0.4

0.6

0.7

0.8

1

0.9

0 0.2 0.4 0.6 0.8 1

S w

k rw ,

k ro

1 imb krw

1 imb kro

fractional flow


IOR : Why is Effective Waterflood

Management Important?

• Effective & Sufficient injection to maintain reservoir pressure =>

Sustain production rate

• Ineffective & Insufficient injection lead to:

– Accelerated reservoir pressure decline

– Oil shrinkage (drop of Bo)

– Increase in oil viscosity

– Increase is produced GOR

– Accelerated gas cap expansion

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Infill Drilling and Pattern Size Reduction

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Reference SPE 26117

Initial Pattern Ineffective pressure supports & Poor Areal Sweep

PSR

Pattern after Infill & PSR

New Injector

New Producer


Injected fluids

only sweep part

of a reservoir

In swept zones,

oil is trapped as

isolated droplets

Some oil is too

viscous to flow

at economic rates

Inject low interfacial tension fluids

• Miscible or near-miscible gas

injection (CO2, N2, Hydrocarbon)

• Chemical flooding (surfactant,

alkaline)

Inject viscous fluids

• Polymer flooding

• Foam flooding

Reduce oil viscosity

• Thermal processes

(cyclic steam stimulation,

steamflood)

• Solvent processes

What Limits Oil Recovery?

Key Question: What is limiting recovery in my field?


EOR Categories

• Miscible – CO2

– Enriched HC Gas

– N2

– Sour or Acid Gas (H2S)

• Immiscible – Gravity

Stable

Gas Injection and Water Alternating Gas (WAG) Processes

Chemically Enhanced Oil Recovery Heavy Oil Recovery

Oil Water Polymer Surfactant

• Surfactant

• Polymer

• Alkaline

• Foam

• Steam Stimulation

• Steam Flooding

• Steam Assisted

Gravity Drainage

• In-Situ Combustion

• Solvent Assisted

Recovery Processes

Gas Water Oil


Miscible Gas Injection

• Miscible flooding is the primary light oil EOR process - targeting

improved displacement of oil

• Susceptible to poor sweep due to gravity and reservoir heterogeneity

• Potential to sweep additional reservoir zones (low perm at top of

reservoir, attic oil)

• Water-alternating-gas (WAG) is commonly used to control gas

breakthrough and reduce gas purchase costs

• Gas supply is usually the primary business driver

Tertiary Recovery

Infill and

Improved

Waterflood

Original

Waterflood

Original Waterflood

Improved WF and

Infill Drilling

Miscible CO 2

Incremental

Recovery

Time

Oil

Rate


Means CO2 Flood Performance

Cumulative Gross Oil Production (MBO)

• Actual recovery in 2010 is beyond the scale of the original chart

Dail

y A

vera

ge P

rod

ucti

on

Ra

te (

kb

od

)

1982

1984

1987

1990

1993

1995

Cont.

WF

2010


3DOs WorkFlow for EOR Projects Reservoir Characterization

Lab Data

Reservoir Simulation

Pilot Testing

Flood Management

Surveillance

Commercial Project Plan

• Field-wide project design and costs

• Full field or multiple segment models

• Field-wide development/depletion plan & economics

Screen Candidate Processes

• EOR process identification

• Injectant sources

• Screening economics

Evaluate Promising Processes In Depth

• Fluid and rock property data collection / lab studies

• Mechanistic / fine-scale modeling

• Screening-level development/depletion plan

Field Tests and Pilots to Resolve Uncertainties

• Objectives and design

• Data collection and interpretation

Implementation, Surveillance, and Operations Reviews / approvals


Indonesia’s EOR Experience

• Before joining 3DOs, one of our EOR Experts had a critical roles in

several of Indonesia’s successful Chemical EOR field trials in

Sumatra

– Surfactant EOR field trial

– Surfactant-Polymer EOR field trial

– Polymer field trial

– Designed full field expansion

• Screening and technical studies

– Gas/WAG in Sumatra and ONWJ fields

– Improved waterflood in Sumatra and ONWJ fields

– Thermal Recovery in several Sumatra fields

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3DOs highly experienced team is ready to help Indonesian oil and gas operators undertake evaluation of mature assets, generate opportunities, conduct technical studies and execute projects to maximize value of mature assets thru:

Global network and database

Competent, qualified team (RE, PE, Geo)

High quality analytical/numerical tools

Integrated workflows

Technology

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Back up Slides

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Polymer Projects

Large-Scale Polymer Floods

• Daqing (China, 9 cp oil) is the only large polymer flood

with a long history

• 11% OOIP uplift

• Waterflooding causes fines mobilization

• ~20% of polymer injectors lose significant injectivity;

mitigated through fracturing or chemical treatments

• Zonal injection control used to ensure adequate

polymer injection into each zone

• Pelican Lake (Canada, 2000-4000 cp) declared

commercial by CNRL

• ~7% OOIP uplift projected

• Pilot started 2005 and commercialized in 2007

• Marmul (Oman, 80cp) polymer flood by Shell

• 27-well development

• Polymer injection capacity: 110 kBD

• Pilot tested in 1980s and 90s; commercial project

started in 2010

CRNL Pelican Lake Pilot

Daqing Polymer Flood


Gravity-Stable Gas Injection

• Miscible or immiscible gas

• Excellent displacement & sweep

• Requires good vertical communication

(across bedding planes)

• Dip and vertical relief are key reservoir aspects

• Gas source and gravity-stable

rates are key economic drivers

• Requires active reservoir management

Crestal Gas Injection into Layered Anticline

3 Years 10 Years 20 Years 30 Years

0.25 1.0 Water Saturation

Hawkins Double-Displacement

Initial

Conditions

End of Middle of End of

WF DDP Gas Inj. GF


How Ineffective Waterflood Impacts on

Production

38

Insufficient VRR Region

D

PAKKQ

o

roo

*

***


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Comparison of Gas-Drive and Water-Drive

Recovery Efficiency in Typical Hawkins Sands

WATER·DRIVE RECOVERY

• 6 6 %

GAS-DRIVE RECOVERY • 86%

GAS-DISPLACEMENT ZONE

WATER-DISPLACEMENT ZONE

• Atphalt Water • Wat.r-lnvlded Oil Column


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