www.getmoreoil.com

Company Background

www.getmoreoil.com

Locations

www.getmoreoil.com

What is a polymer gel?

www.getmoreoil.com

99% Water + Polymer + Cross-linker = Immobile Gel

• used for profile modification and in-depth

conformance control at injection wells • used to shut-off excessive water at producing wells in

natural waterdrive reservoirs and waterfloods

www.getmoreoil.com

Factors that determine recovery efficiency

www.getmoreoil.com

Vertical Sweep Efficiency: the volume of rock that is contacted in the vertical plane Areal Sweep Efficiency: the volume of rock that is contacted in the horizontal plane Displacement Efficiency: the volume of mobile oil displaced from the contacted rock

www.getmoreoil.com

Injector Producer

Injected fluid

www.getmoreoil.com

By-passed oil (low K)

Injector Producer

Swept layer (high K)

By-passed oil (low K)

Injection “cycling”

www.getmoreoil.com

Areal Sweep Ideal Case (Radial Flow)

10 www.getmoreoil.com

Realty

www.getmoreoil.com

By-passed oil

By-passed oil

By-passed oil

By-passed oil

By-passed oil

By-passed oil

www.getmoreoil.com

Realty

Injector Producer

gel

www.getmoreoil.com

Injector Producer

gel

www.getmoreoil.com

Injector Producer

gel

www.getmoreoil.com

Injection water is diverted to other areas of the reservoir and sweeps by-passed oil to the producing wells

www.getmoreoil.com

Injection drive fluid is diverted to other areas of the reservoir and sweeps by-passed oil to the producing wells

www.getmoreoil.com

Data needed to assess pro-mod treatment

www.getmoreoil.com

Base map showing producer & injector well locations

Geological maps (isopach, structure, HCPV, etc.)

Reservoir rock & fluid properties

Geological description

Core reports

Historical tabular oil & water production data by well

Historical tabular injection rate & pressure data by well

Injection profile logs

Openhole logs

Wellbore diagrams

Well histories

www.getmoreoil.com

Sizing the job

www.getmoreoil.com

By-passed oil

By-passed oil

www.getmoreoil.com

WOR Method

www.getmoreoil.com

Fracture Breakthrough (smaller Swept PV)

1

10

100

1000

10000

1.00

10.00

100.00

1000.00

0

20

,00

0

40

,00

0

60

,00

0

80

,00

0

10

0,0

00

12

0,0

00

14

0,0

00

16

0,0

00

18

0,0

00

20

0,0

00

22

0,0

00

24

0,0

00

26

0,0

00

28

0,0

00

30

0,0

00

32

0,0

00

34

0,0

00

36

0,0

00

38

0,0

00

40

0,0

00

42

0,0

00

44

0,0

00

46

0,0

00

48

0,0

00

BO

PD

& B

WP

D

WO

R

Cum. Oil Bbls.

Cumulative Oil vs. WOR

WOR Begin Water Injection BOPD BWPD

Swept MPV 140,000 Bbls

Oil Response Water Breakthrough

www.getmoreoil.com

Matrix Breakthrough (larger swept PV)

Swept MPV 140,000 bbls

www.getmoreoil.com

140,000 bbls

assign proportionate share to surrounding injectors

www.getmoreoil.com

www.getmoreoil.com

Volumetric Method

Example Injector-centered Pattern

www.getmoreoil.com

Estimate “serviceable” area

Area = 10 acres

www.getmoreoil.com

Estimate thief height in “serviceable” area from injection profile log 10’

www.getmoreoil.com

High K Swept Layer

Low K By-passed Layer

Low K By-passed Layer

10’ 70’

100% of Flow Capacity into only 14.3% of Pay

www.getmoreoil.com

Height = 10’ Porosity = 20%

Calculate Moveable Pore Volume (“MPV”) of high K layer (thief) over the “serviceable” area

More difficult to estimate swept MPV of fractures using Volumetric Method (geometry unknown)

www.getmoreoil.com

www.getmoreoil.com

How much of the MPV do we want to fill with polymer? More if

Kvh is high, and less if Kvh is low.

www.getmoreoil.com

General treatment procedure 1) No well modification required to accommodate job 2) Rig up polymer blending and injection unit to water source and

wellhead 3) Inject treatment (“bullhead”-style) with entire producing

interval exposed to polymer 4) Polymer injected as a liquid with delayed gelation allows for

deep placement of large volumes 5) Polymer will follow the path of least resistance (i.e. high

permeability swept rock) 6) Over-displace polymer solution from wellbore 7) SI well for several days to allow gel time to form 8) Reactivate well

36’

Polymer Technology for Water Shut-off • Profile Modification • Mobility Control

www.getmoreoil.com 8.5’

6.2’

Mobile Polymer Unit

www.getmoreoil.com

0

200,000

400,000

600,000

800,000

1,000,000

1,200,000

0

50

0,00

0

1,0

00,

000

1,5

00,

000

2,0

00,

000

2,5

00,

000

3,0

00,

000

3,5

00,

000

4,0

00,

000

4,5

00,

000

5,0

00,

000

5,5

00,

000

6,0

00,

000

6,5

00,

000

7,0

00,

000

Cu

mu

lati

ve p

si-d

ays

Cumulative Injection Bbls.

Typical Hall Plot

Hall Plot Polymer Gel Treatment

First indicator of change is decreased injectivity at treated well (higher injection pressure is required to inject water into lower permeability rock)

www.getmoreoil.com

51,000 bbls

www.getmoreoil.com

Phosphoria Injection Pattern

30 acres

www.getmoreoil.com

www.getmoreoil.com

www.getmoreoil.com

Portwood (EOGA), Lackey (Citation), & Abel (Citation)

www.getmoreoil.com

Data needed to assess WSO treatment

www.getmoreoil.com

Reservoir rock & fluid properties

Geological description (how water gets to the wellbore)

Core reports

Historical tabular oil & water production data

Static SI and producing fluid level

Openhole logs

Wellbore diagram

Well history

www.getmoreoil.com

Gel polymer for WSO at producing wells

1

10

100

1,000

10,000

1 3 5 7 9

11

13

15

17

19

21

23

25

27

29

31

33

35

37

39

41

43

45

BO

PD

& B

WP

D

Time

BOPD BWPD

flat water and declining oil

indicate max pump capacity,

and increasing fluid level

Typical High Water-cut Well

www.getmoreoil.com

www.getmoreoil.com

Sizing the job

Distance Matters! deeper placement = more oil

(but how deep?)

Productivity Index (PI) estimates maximum flow capacity at zero pressure gradient

→ High PI = large flow features = large PV = large gel volume → Low PI = small flow features = small PV = small gel volume

www.getmoreoil.com

www.getmoreoil.com

www.getmoreoil.com

General treatment procedure

1) Pull production equipment 2) Install tubing & packer above top perforation or openhole section 3) Aggressively acidize well 4) Rig up polymer blending and injection unit to water source and

wellhead 5) Inject treatment (“bullhead”-style) with entire producing interval

exposed to polymer 6) Polymer will follow the path of least resistance (i.e. offending

water flow conduits) 7) Over-displace polymer solution from wellbore 8) SI well for several days to allow gel time to form 9) Reactivate well

www.getmoreoil.com

www.getmoreoil.com

www.getmoreoil.com

www.getmoreoil.com

Whisonant (Marathon) & Hall (Marathon)

www.getmoreoil.com

Old Well #1

www.getmoreoil.com

Old Well #2

www.getmoreoil.com

www.getmoreoil.com

57

New Well

www.getmoreoil.com

Phosphoria Formation –

Candidate Selection, CRM, Gel

Polymer Treatment Model

www.getmoreoil.com

Components of the Methodology

Step I – Production Diagnostics, Data Analysis, Data

Preparation, Sector Selection Production Diagnostics, WOR vs Cumulative Production, CRM, Core

Analysis, Upscale Simulation Layers

Step II – Estimation of Depth and Volume of

Treatment Apparent Viscosity using Viscoelastic Model, Couple with Fluid Flow

Model, Generate Depth and Volume of Gel Polymer Injected

Step III – Apply Gel Polymer Footprint in the

Numerical Sector Model and Compare Effects of

Continued Waterflood OR Fracture Modeling Calibrate Numerical Model to Current Watercut conditions, Upload

Gel polymer Footprint, Run two Cases to Compare (a) Continued

Waterflood and (b) Waterflood after Treatment

www.getmoreoil.com

Phosphoria Formation – Gel

Polymer Treatment (Fractured

Producer)

www.getmoreoil.com

Maximum Oil Rate

www.getmoreoil.com

Zero Time Cumulative Oil

www.getmoreoil.com

Zero Time Cumulative Water

www.getmoreoil.com

Production Diagnostics – 5713

coning

channeling

www.getmoreoil.com

Aquifer

Oil Zone

www.getmoreoil.com

History Match – 5713 fracture distribution – run 1

Ratio = 1

www.getmoreoil.com

History Match – 5713 watercut – run 1

www.getmoreoil.com

History Match – 5713 watercut – run 2

Ratio = 1.5

www.getmoreoil.com

History Match – 5713 watercut – run final

Ratio = 6

www.getmoreoil.com

Water (Aquifer) www.getmoreoil.com

Post Treatment Fractures Shutoff

Ratio = 6 Fractures shut off

www.getmoreoil.com

Treatment Volume 5713

3,000 bbls

10,000 bbls

www.getmoreoil.com

Effective Fracture Shutoff – 5713

www.getmoreoil.com

Phosphoria WSO – Actual Treatment

www.getmoreoil.com

Phosphoria WSO – Model Comparison

www.getmoreoil.com

Phosphoria WSO – Model Fracture Shutoff

www.getmoreoil.com

www.getmoreoil.com

Phosphoria – Gel Polymer

Treatment (Injector)

www.getmoreoil.com

CRM Results – Gains Matrix - Phosphoria

www.getmoreoil.com

CRM Results – Gains Matrix - Phosphoria

www.getmoreoil.com

Fraction of Water Injected

www.getmoreoil.com

Total Liquid Produced

www.getmoreoil.com

(Produced – Injected)

www.getmoreoil.com

Step I – Data Preparation -- Layered Reservoir Properties

Oil viscosity ~ 200 cp

Mobility Ratio ~ 133

Kv/kh ~ 0.1

Effects of viscous fingering

and permeability contrast

www.getmoreoil.com

Step II – Estimate Depth and Volume of Invasion

Delshad, M.. et. al 2008; Stavland, A et . al 2010

1

2max

21

20 2

1

exp11

n

effr

n

effwpwapp

p

e

w

t

w

p

p

t

r

r

h

q

r

r

h

qp ln

007081.0ln

007081.0

Apparent viscosity calculation for different flow regimes (shear thinning, shear thickening, Newtonian)

Pressure Drop calculation in a layered system

www.getmoreoil.com

Step II -- Depth and Volume of Invasion

www.getmoreoil.com

Step III – Comparison of Performance

Case I – continued waterflood

Case II – waterflood post treatment

www.getmoreoil.com

Step III -- Comparison of Oil Rates

IBO ~ 50 M STB in 10 years

www.getmoreoil.com

Step III -- Comparison of Watercut

www.getmoreoil.com

www.getmoreoil.com