Reservoir And Production Conformance In Dev Wells_quito_final

Reservoir & Borehole Diagnostics/Conformance for EOR in Development Wells Maged Fam

Dr. Luis Quintero

Formation & Reservoir Solutions Latin America

Production Management Houston, TX

Region Manager

Global Advisor

Topics  Global Oil Resources & Reserves  What is EOR  What is Conformance  Reservoir, Production, Well Integrity Diagnostics  Reservoir Diagnostics using Pulsed Neutron Technology   and C/O Interpretation and Case Histories  Chi ModelingSM – Silicon & Oxygen Activations  Production Diagnosis / Surveillance  PLT and Ultra-Sonic Technology and Applications  Well Integrity and Zonal Isolation Diagnostics  Perforation Techniques Considerations  EOR in Heavy Oil  Conclusion © 2013 Halliburton. All Rights Reserved.

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4

World’s Oil in Place Original Oil in Place 400

Conventional

300

<100 cP

Heavy Oil

200

100-10000 cP

Extra Heavy Oil 10,000 cP

100 0

D. Wightman (1997)

Total Oil In Place ≈ 14.0 Trillion bbl. < 100 cp 100 – 10,000 cp > 10,000 cp

4.5 Trillion bbl. 3.5 Trillion bbl. 6.0 Trillion bbl.

1 Trillion = 1,000,000,000,000 © 2013 Halliburton. All Rights Reserved.

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Total Produced ≈ 1.1 T. bbl. 90 % < 100 cp 10 % > 100 cp

World’s Oil Reserves OPEC Share of World Crude Oil Reserves 2011

Resource = Volume of Hydrocarbon in Place

OPEC Proven Crude Oil Reserves, end of 2011 (Billion Barrels, OPEC Share) Venezuela

297.6

24.8%

Iraq

141.4

11.8%

Libya

48.0

4.0%

Algeria

12.2

1.0%

Saudi Arabia

265.4

22.1%

Kuwait

101.5

8.5%

Nigeria

37.2

3.1%

Angola

10.5

0.9%

Iran, I.R.

154.6

12.9%

UAE

97.8

8.2%

Qatar

25.4

2.1%

Ecuador

8.2

0.7%

Source OPEC Annual Statistical Bulletin 2012

30% Oil Sand Bitumen

Reserve = Volume of Hydrocarbon Economically Recoverable

30% Conventional Oil

30% Extra Heavy Oil

1 Billion = 1,000,000,000 Source: Wikipedia © 2013 Halliburton. All Rights Reserved.

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15 % Heavy Oil

Reserve Estimates Oil In Place

7758A  h    1  Sw  No  Bo

Gas In Place

43560A  h    1  Sw  Ng  Bg

Reserves

R  NF

r

No = oil in place, stb Ng = Gas in Place, scf A = drainage area, acres Bo = Oil formation volume factor (rbbl/stb) Bg = Gas formation volume factor (rcf/scf) h = individual zone thickness, ft Φ= porosity, fraction Sw = water saturation, fraction Fr = Recovery Factor

© 2013 Halliburton. All Rights Reserved.

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EOR Enhanced Oil Recovery “EOR” is a generic term for techniques used to increasing the amount of crude oil that can be extracted from a reservoir. Enhanced oil recovery is also called improved oil recovery or tertiary recovery (as opposed to primary and secondary recovery). Common EOR methods:  Gas Injection  natural gas  Nitrogen  CO2  Thermal Methods  Steam Injection  Fire Flood  SAGD  Chemical  Polymer Flooding  Microbial Injection  Liquid CO2 Flooding © 2013 Halliburton. All Rights Reserved.

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EOR EOR is about increasing the recovery Factor “Fr” Enhanced Oil Recovery Project at Weyburn, Canada

Additional 1% Fr = 2 – 3 years of additional Reserves © 2013 Halliburton. All Rights Reserved.

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Primary vs. Enhanced Oil Recovery

Production - 1000 bbls/day of Oil

Primary vs. Enhanced Oil Recovery Example 3,000 2,500

Primary Recovery

2,000

Injection

1,500

EOR

1,000 Oil Production

500 0

0

© 2013 Halliburton. All Rights Reserved.

10

20 Years

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30

40

Hydrocarbon Production Rates

A ( P1  P2 ) QK   L High Permeability

Where: Q = rate of flow, cm3/sec A = cross sectional area, cm2 L = Length, cm P1 = initial pressure, psi P2 = producing pressure, psi m = Fluid viscosity, cP

Low Permeability

Productivity Index

h k PI   R   ln r w

© 2013 Halliburton. All Rights Reserved.

α = numerical coefficient depending , among other thing, on units h = reservoir thickness A = drainage area k = reservoir permeability μ = reservoir fluid viscosity R = well drainage radius Φ = porosity rw = well bore radius MF - 10

EOR

Conventional Oil Recovery

Oil Recovery/Production Mechanisms

Primary Natural Flow

Water Flood

Thermal Steam Hot Water Combustion

© 2013 Halliburton. All Rights Reserved.

Secondary Tertiary Gas Injection

Chemical Surfactant Polymer Alkaline

CO2 Hydrocarbon Nitrogen MF - 11

Artificial Lift

Pressure Maintenance

Other Microbial Acoustic Waves Electromagnetic Mechanical

Conformance Is a Process for Optimizing / Enhancing Production Management Control &/or Alteration of Undesired Fluids &/or Deposits e.g.: Water, Gas. Sand, Asphaltenes Initial Evaluation

Reservoir Characterization

Evaluation of Results

Problem Diagnosis

Execution

Selection of Proper Solution © 2013 Halliburton. All Rights Reserved.

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EOR - Integration of Services & Solutions Experts & Specialists

Stimulation & Treatment

Wireline & Perforating

Coiled Tubing

Completion & Isolation

© 2013 Halliburton. All Rights Reserved.

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Technologies & Services for Optimizing EOR Reservoir & Production Diagnostics - RMT-Elite / GR

- QuikLook Dynalink

- PLT / CAT / Gas Holdup

Spectral Flow

- Spectral Flow Log

- T-FAS

- Dynalink

- EZ Gauge

RMT-Elite PLT

CAT T-FAS

Well Integrity Diagnostics: Swell Packer

- Swell Packer - CAST-V - RCBL

HPI

CAST-V

- Expandable Packers - HPI RCBL © 2013 Halliburton. All Rights Reserved.

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Technologies & Services for Optimizing EOR Experts & Specialists: - NEXUS - EDM EDM

- DMS - SpecDecomp

SpecDecomp DMS

NEXUS

- Emeraude - PLATO

Perforating Techniques:

SurgePro

- Conventional - SurgePro

StimGun StimTube

- StimGun - StimTube © 2013 Halliburton. All Rights Reserved.

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Technologies & Services for Optimizing EOR Reservoir Stimulation - GasPerm1000

CW-Frac GasPerm1000

- CW-Frac

My-T-Oil V

- Expedite - SandWedge - My-T-Oil V

Expedite

- Optikleen-WF SandWedge

- SurgiFrac - CobraMax

OptiKleen-WF

CobraMax

SurgiFrac © 2013 Halliburton. All Rights Reserved.

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Technologies & Services for Optimizing EOR Water Control: PermSeal

- WaterWeb - H2Zero

WaterWeb

H2Zero

- PermSeal - BackStop - Thermatek - MocOne - QuikLook

Thermatek

BackStop QuikLook

MocOne

© 2013 Halliburton. All Rights Reserved.

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Technologies & Services for Optimizing EOR Chemical Treatment & Cleaning:

Guidon AGS 800

- PulsonixTF

PulsonixTF

Water Oil

750

623

600

DuraKleen

400

- DuraKleen

340

200

22

0 Initial Perm (md)

- Guidon AGS - CoilGard

Final Perm (md)

LO-Gard

- LO-Gard

CoilGard

- CoilSweep

CoilSweep

- Hydra-Blast - DeepWave StimWatch

- StimWatch Hydra-Blast

© 2013 Halliburton. All Rights Reserved.

DeepWave

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Technologies & Services for Optimizing EOR Sand Control:

PropStop

Expedite

- PropStop - SandTrap

SandWedge

- Expedite - SandWedge SandTrap

Special Services: - Coiled Tubing

Coiled Tubing Enhebrado

- Coiled Tubing Enhebrado - Well Tractor © 2013 Halliburton. All Rights Reserved.

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Well Tractor

Reservoir, Wellbore Integrity & Production Diagnostics

Producer

Water Cut %

1

2

3 4

Time

Injector

Reservoir Diagnosis:  Coning (water or gas)  Channeling thru high K channels  Water injection profile  Relative permeability profile  Unplanned fracture extension Production Diagnosis/Surveillance  Plugged perforations  Fluid % production contribution  Undesired fluid entry downhole  Production rates evaluation downhole Well Integrity Diagnosis:    

© 2013 Halliburton. All Rights Reserved.

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Casing damage Channels behind casing Seal rupture / breakdown Completion near water zone

Reservoir, Production & well Integrity Diagnosis Tools Reservoir & Production Diagnosis:  RMT- Elite  TMD-L  Spectral Flow Log  PLT / CAT / Gas Holdup  Dynalink  QuikLook  T-FAS  EZ Gauge

Completion & Borehole Diagnosis:  CAST-V  CBL & RCBL

Top of Salt

 MIT & MTT © 2013 Halliburton. All Rights Reserved.

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Reservoir Diagnosis

Water, Oil & Gas Saturations / Remaining Saturations

Reservoir Monitoring and Water/Oil Saturation Estimation in Completed Wells

Carbon Oxygen “C/O” & SIGMA “Σ” © 2013 Halliburton. All Rights Reserved.

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Reservoir Monitoring and Water Saturation Estimation in Completed CH Wellbores Carbon Oxygen “C/O” & SIGMA “Σ” Reservoir Monitor Tool – Elite (RMT-E)

© 2013 Halliburton. All Rights Reserved.

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Main Technologies used for CH Reservoir Monitoring  Pulsed Neutron Capture () -- PNC  Oil Saturation  High Salinity Formation Water  Gas Saturation  High Salinity Formation Water  Low Salinity Formation water

Sigma “” is the capture cross section, for thermal neutron absorption, of a volume of matter.

 = 4550 / TAU  = capture cross section (capture units) TAU = neutron decay time (usec)

 Pulsed Neutron Spectral (C/O) -- PNS 

Oil Saturation & Gas identification  Variable, Unknown Salinity and/or Fresh Formation Water

© 2013 Halliburton. All Rights Reserved.

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Pulsed Neutron Capture Definitions Neutron interaction with a matter can be either scattering or absorption reactions. Scattering can result in a change in the energy and direction of motion of a neutron but cannot directly cause the disappearance of a free neutron. Absorption leads to the disappearance of a free neutron as a result of a nuclear reaction with formation of new nuclear and another particle or particles such as protons, alpha particles and gamma photons

Neutron capture: is a kind of nuclear reaction in which an atomic nucleus collides with one or more neutrons and they merge to form a heavier nucleus.

Capture Cross Section: The macroscopic cross section for the absorption of thermal neutrons of a volume of matter, measured in capture units (c.u.). Sigma is also used as an adjective to refer to a log of this quantity. Sigma is the principal output of the pulsed neutron capture log, which is mainly used to determine water saturation behind casing.

© 2013 Halliburton. All Rights Reserved.

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Reaction Sequence of High Energy Neutrons GR/CCL Telemetry 1 11/16”

Inelastic Measurement

Capture Measurement (Thermal)

Fast & High Energy Interaction Si, Ca, C and O Spectrum are measured. Windows algorithm for C/O and Ca/Si ratios

V. slow & Low Energy Interaction H, Si, Ca, Cl & Fe Spectrum are measured. Yields are used in basic mineralogy. Sigma & ratios of counts porosity

Capture 

Inelastic 

Thermal

2 1/8” RMT (BGO)

Inelastic  © 2013 Halliburton. All Rights Reserved.

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Elastic

Neutron Decay Steps Neutron Decay in Time

Inelastic / Elastic High Energy

Fast

Elastic Intermediate Epithermal

Elastic / Absorption Thermal

This image cannot currently be display ed.

This image cannot currently be display ed.

Elastic Gamma Ray Inelastic Gamma Ray 10 μSec.

N © 2013 Halliburton. All Rights Reserved.

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Capture Gamma Rays

Neutron energy classifications and GR producing reactions for pulsed neutron well logging... Class

Energy range

Time

Source

14 MeV to 10 MeV

0

inelastic (C,O,Ca,Si,Fe) activation (O, Si, Fe)

High Energy

10 MeV to 100 keV

<1 sec

inelastic (C,O,Ca,Si,Fe) activation (Si, Fe)

<2 sec

inelastic (Fe) activation (Fe)

Fast

Epithermal

Thermal © 2013 Halliburton. All Rights Reserved.

100 kev to 100 ev 100 ev to .1 ev ~0.025 ev

Predominant Reactions

inelastic (Fe) <20 sec capture (Fe) activation (Fe, Al) <1 msec MF - 28

capture (H,Si,Ca,S,Fe,Ti,K,Cl) activation (Al, Fe)

RMT-E Timing Diagram Elemental Yields (Si, Ca, K, Fe, S, Ti, H, Cl) C/O & Ca/Si

SIGMA Σ formation © 2013 Halliburton. All Rights Reserved.

Water Movement from Oxygen Activation MF - 29

 Design Principles  Bismuth Germinate (BGO) Detectors  Isolated Detector Section  Combinable with PLT (Production Logging Tools)  Optimized Simultaneous Measurements  C/O & Σ for saturations estimation, fluid type / contacts detection  Elemental Contributions: Si, Ca, K, Fe, S, Ti, H, Cl, C, O for lithology analysis

Ф from capture and inelastic count rate ratios  Oxygen Activation for detecting water movement

Dewar Heat Sink BGO

© 2013 Halliburton. All Rights Reserved.

housing

BGO

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PN Generator

 Thru Tubing (2 7/8” – I.D. 2.375”) logging 2 1/8” tool O.D.  Temp. limit 325º F & Press. Limit 15,000 psi Borehole Fluid

 Combinable with PL tools for Production analysis  Detection of Water Movement

Casing

 Station or continuous measurements  Inside & Outside Casing  Water movement velocity measurement

Cement

 Two operation Modes:

RMT- E

 Inelastic mode  C/O, IRIN (ΦD), RCAP (ΦN) Elemental yields, , OA  Capture Mode   RIN (ΦD), RNF (ΦN), Elemental Yields, OA

Formation

 Max Logging Speed:  3 ft/min  Inelastic mode (3 passes or 1 Pass 1 ft/min)  15 ft/min  capture mode Borehole © 2013 Halliburton. All Rights Reserved.

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Detectors Used by Service Companies Detector

DIAMETER LENGTH

DENSITY

Energy Resolution*

BGO

1.4”

6”

7.13 gm/cc

9.3 %

GSO

1.1”

4”

6.71 gm/cc

8%

NaI

1.11”

6”

3.67 gm/cc

6.5 %

* : at 662 keV for a 1 cm3 Crystal

BGO : Bismuth Germanate : Bi4Ge3O12 cubic crystals GSO : Gadolinium Oxyorthosilicate : NaI : Sodium Iodide : NaI © 2013 Halliburton. All Rights Reserved.

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Pulsed Neutron Applications Capture “Σ” Applications

Inelastic “C/O” Applications

O Activation Applications

 Reservoir Monitoring in high Formation Water Salinity

 Reservoir Monitoring in Fresh or unknown Formation Water Salinity

 Oxygen Activation Log for Water Flow Detection

 Water Saturation “Sw”  Reservoir Fluids Contacts in completed (CH) wellbores  Capture Porosity similar to Neutron Porosity  Spectroscopy Log for Lithology

© 2013 Halliburton. All Rights Reserved.

 Oil Saturation “So”  Reservoir Fluid Contacts in completed (CH) wellbores  Inelastic Porosity similar to Density Porosity  Spectroscopy Log for Lithology

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 Silicon Activation Log for Gravel Pack Evaluation, Lithology and differentiation between Limestone vs. Sandstone

© 2013 Halliburton. All Rights Reserved.

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Typical  Values Lithology / Fluid Type Sandstone Limestone Dolomite Shale Oil Gas Fresh Water Salt Water (100 Kppm) Salt Water (240 Kppm)

 Tipical values used @20C,c.u. 7 to 14 7 to 15 8 to 12 20 to 50 16 to 22 2 to 15 22.20 59 119

10 12 9 Vary by Formation

20  (Temperature, Pressure & Sp. Gravity)

20 59 119

c.u. : Capture Units

© 2013 Halliburton. All Rights Reserved.

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Typical  Values of Different Elements 

MINERAL



Quartz SiO2

4.3

MINERAL

Calcite CaCO3

7.3

Iron-Bearing Minerals

Dolomite CaCO3.MgCO3

4.8

Iron Fe

220

Geothite FeO(OH)

89.0

Hematite Fe2O3

104

Magnetite Fe3O4

107

Limonite FeO(OH).3H2O

80.0

Pyrite FeS2

90.0

Siderite FeCO3

52.0

Feldspars Albite NaALSi3O8

7.6

Anorthite CaALSi2O8

7.4

Orthoclase KAlSi3O8

15.0

Evaporites Anhydrite CaSO4

13.0

Gypsum CaSO4.2H2O

19.0

Iron-Potassium Bearing Minerals

Halite NaCl

770

Glauconite (green sands)

25 +/-5

Sylvite KCl

580

Chlorite

25 +/-15

Carnallite KCl.MgCl2.6H2O

370

Mica (Biotite)

35 +/-1

Borax Na2B4O7.10H2O

9000

Illite Shale

37 +/-5

Kermite Na2B4O7.4H2O

10500

Others

Coal

Pyrolusite MnO2

440

Lignite

30 +/-5

Manganite MnO(OH)

400

Bituminous coal

35 +/-|

Cinnabar HgS

7800

Anthracite

22 +/-5

© 2013 Halliburton. All Rights Reserved.

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 in c.u. (capture Units)

Typical Log Responses When to run  Log ..?

Inelastic Ratio Capture Ratio

GAMMA RAY

60

Ф (PU) x Sal. (Kppm) = YY

SIGMA  - c.u.

0

Shale

YY < 500  No

GAS (< 15)

1000 > YY > 500  Possible

Oil (16-22)

YY > 1000  Good Results

Clean Sandstone

Fresh Water (22.2)

Ex.: 20 pu x 20 kppm = 400  No

Salt Water (56) 90 Kppm

25 pu X 50 kppm = 1250  Good Results

Shale

© 2013 Halliburton. All Rights Reserved.

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Hydrocarbon Shaly Rock Model Total Volume = 1

Shale Porosity

1=Vma + e +VSh

H.C. Volume

Vhc= (1-SW)*e Rock Matrix Volume

Vma=1-e - VSh

Rock Matrix Water Volume

Vw= SW*e Shale Volume

© 2013 Halliburton. All Rights Reserved.

VSh MF - 39

Hydrocarbon Shaly Rock Model Log = ma * vma + Sh * vSh + w * vw + hc * vhc Vma = 1 - e - VSh VSh Vw = e* Sw

Log

ma

w hc Sh

Vhc = e * ( 1 - S w) © 2013 Halliburton. All Rights Reserved.

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“SigmaSat”

© 2013 Halliburton. All Rights Reserved.

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© 2013 Halliburton. All Rights Reserved.

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Carbon Oxygen Ratio “C/O” Logs What exactly do we measure ?  The Carbon and Oxygen content associated with fluids and Matrix  Fluids: Carbon in Oil & Oxygen in Water  The C/O represent the relative ratios of Water and Oil

C/Ο = A

C matrix + C porosity + C borehole

A: constant reflects the relative flux-averaged inelastic neutron cross section for Carbon & Oxygen

Ο matrix + Ο porosity + Ο borehole

O

H

H

H H2O (Water) © 2013 Halliburton. All Rights Reserved.

Low C/O

H

H

H

H

H

H

H

H

C

C

C

C

C

C

C

C

H

H

H

H

H

H

H

H

High C/O MF - 43

C8H18 (Octane )

H

RMT-E Timing Diagram Elemental Yields (Si, Ca, K, Fe, S, Ti, H, Cl) C/O & Ca/Si

SIGMA Σ formation © 2013 Halliburton. All Rights Reserved.

Water Movement from Oxygen Activation MF - 44

RMT-E Raw Spectra

© 2013 Halliburton. All Rights Reserved.

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C/O Spectra 40

35 pu FW S.S 36 pu Oil S.S.

30

26 pu FW L.S.

x10

-3

Normalized Counts

X5

Si

Ca

C

20

C

O

10

0 2

© 2013 Halliburton. All Rights Reserved.

4

Energy (MeV)

6

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8

O

RMT-E C/O and Ca/Si Fan Charts for 7” csg/10” bh Corrected C/O

Corrected Ca/Si

0.580

1.650

0.560

1.600

CO

0.080

0.060 0.540

1.550

4.5/6 Oil 4.5/6 SW 4.5/6 FW 7/10 FW 7/10 SW 7/10 Oil 9.6/10 fw 9.6/10 sw 9.6/10 oil

4.5/6 Oil 4.5/6 SW

0.500

0.040

1.500

 CO

R"co

R "casi

0.520

1.450

7/10 FW 7/10 SW 7/10 Oil

0.020

Limestone

4.5/6 FW

9.6/10 fw 9.6/10 sw

1.400

0.480

9.6/10 oil

0.000 1.350

0.460

Sandstone

0.440 0

0.1

0.2

0.3

Porosity

© 2013 Halliburton. All Rights Reserved.

-0.020

1.300 0.4

0.5

0

0.1

0.2

0.3

Porosity MF - 47

0.4 0 0.50.1

0.2

0.3

Porosity

0.4

0.5

RMT-E Raw data Basic Quality Control  Individual Log Passes  Check Repeatability  Verify that different passes are on depth

© 2013 Halliburton. All Rights Reserved.

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RMT-E Corrected Log data  Log Stacking  Environmental Corrections  Curves Normalization

© 2013 Halliburton. All Rights Reserved.

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C/O Oil Saturation Equation ΔC/O = R C/O - 0.2R Ca/Si + 0.02Φ - 0.185 + k (1 - 0.37Φ)ΔC/O So = Φ(ΔC/O + 0.178ρ hc )

© 2013 Halliburton. All Rights Reserved.

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Lithology Independent Oil Saturation “So”

 CO 0.080

0.060 4.5/6 Oil 4.5/6 SW 4.5/6 FW 7/10 FW 7/10 SW 7/10 Oil 9.6/10 fw 9.6/10 sw 9.6/10 oil

CO

0.040

0.020

0.000

-0.020 0

0.1

0.2

0.3

0.4

0.5

Porosity © 2013 Halliburton. All Rights Reserved.

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RMT-E Visual Interpretation

Water Flow Behind Pipe O Activation

© 2013 Halliburton. All Rights Reserved.

Gas Indicator Count Rates Ratio Oil Indicator C/O

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RMT-E Final Interpretation

 Porosity  Gas Saturation  Oil Saturation  Water Saturation  Water Flow  Lithology indicators

© 2013 Halliburton. All Rights Reserved.

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RMT-E Final Interpretation

Gas in the Tubing/Casing Annulus

Oil in the Tubing/Casing Annulus

Gas in Casing

Oil in Casing

© 2013 Halliburton. All Rights Reserved.

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© 2013 Halliburton. All Rights Reserved.

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Chi ModelingSM Black curves are the actual triple-combo logged data Colored curves created by CHI Modeling

© 2013 Halliburton. All Rights Reserved.

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Chi ModelingSM Data Input Step Gamma Ray - GR

NN Processing Step

Data Output Step

Intrinsic Sigma - SGIN Inelastic near/far ratio - RIN

NPHI

Capture near/far ratio - RTMD

RHOB

Near detector count rate - NTMD

Rt

Far detector count rate - FTMD Near sigma borehole - SGBN

© 2013 Halliburton. All Rights Reserved.

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Chi ModelingSM Required Information:  Open hole Data for Training the NN model  Borehole Completion History  Production / Injection History  Caliper data (if any)  Cement Evaluation Data  All Perforations past and present © 2013 Halliburton. All Rights Reserved.

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Chi ModelingSM Workflow Step - 1

PN Logs

Train

OH Logs

CHI Modeling Network Training well or wells © 2013 Halliburton. All Rights Reserved.

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SM

Chi Modeling Workflow Step – 2 & 3 Apply PN Logs

Trained CHI Modeling

Output OH Logs

Network

Application Well 1, 2, etc. © 2013 Halliburton. All Rights Reserved.

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Logged Triple Combo Log

121/4” Hole

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Logged NPHI vs. Chi Modeling NPHI

Modeled NPHI

121/4” Hole

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Logged NPHI

Logged Rhob Log

121/4” Hole

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Chi Modeling Rhob Curve

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Chi Modeling Rhob / NPHI Curves vs. Logged

Modeled Curves © 2013 Halliburton. All Rights Reserved.

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Logged Curves

SM

Chi Modeling

Summary

 Predict Triple Combo responses from Cased Hole PN logs  Alternative method when Triple Combo data cannot be obtained in Open Hole. The NN training and processing needs to be applied within the same stratigraphic intervals for best results  The processing can typically be extrapolated for use as far as 30 miles or more provided detailed QC and reservoir continuity © 2013 Halliburton. All Rights Reserved.

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© 2013 Halliburton. All Rights Reserved.

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Silicon Activation

Gamma Ray Detector Above Activated Silicon has a 2.24 min. Half-life

High Energy (14-MeV) Neutron Generator

Gamma Ray Detector Below

n

Upper Detector

Lower Detector

(1.74 MeV) Si16

© 2013 Halliburton. All Rights Reserved.

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Silicon Activation - Example

© 2013 Halliburton. All Rights Reserved.

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Oxygen Activation  Energy Levels of Gamma Rays measured by a detector 5

NEAR OAI FAR OAI

NORMALIZED COUNTS

4

OBI

 256 Channel Recording of the Gamma Ray Energies from 0 to 8 MeV

OAI

3

 Activated Oxygen in Water has a 6.13 MeV gamma ray

2

 Spectral shape allows determination of flow location

1

• Inside or Outside Pipe determination using Compton Ratio measurement • CRAT = OAI/OBI

0 0

20

40

60

80

100

© 2013 Halliburton. All Rights Reserved.

120 140 CHANNEL

160

180

200

220

240

260

MF - 71

Oxygen Activation To Measure Water Flow movement O16 Gamma Ray Detector

 (6.13 MeV)

Beta Decay

N16 7.13-sec Half-Life

High Energy (14-MeV) Neutron Generator

n

Oxygen Activation

O16 © 2013 Halliburton. All Rights Reserved.

MF - 72

Oxygen Activation - Example -.1 .05

Calcium Yield Silicon Yield

.6 .8

260 -10

Sigma Borehole Gamma Ray

60 110

.05 Oxygen Activation 2.55 55K Inelastic Count Rate 8.5 Ratio Inelastic/capture -1.5 23K Far Count Rate 8 Ratio Near/Far 3 65K Near Count Rate 10 0  60 Sigma Formation - Corrected 0

Water Flow X600

X700

X800

© 2013 Halliburton. All Rights Reserved.

MF - 73

0 0 0

Pulsed Neutron Applications Summary:  Base log for future monitoring of “ Sw “  Formation fluids contacts detection  Identification of Hydrocarbon zones  Development and expansion of Gas zones  Differentiate between Gas and Oil  Production Analysis  Detection of water movement  Definition of fluids contacts inside the wellbore  Flow monitoring  Exploring old wells  Combining old resistivity logs with RMT-E porosity  Abandoned wells logging for bypassed Hydrocarbon zones detection

© 2013 Halliburton. All Rights Reserved.

MF - 74

Pulsed Neutron Applications Summary:  Open Hole Logs replacement in case of borehole problems  Standalone analysis after invasion dispersion  Combining OH LWD Resistivity logs with CH RMT porosity  Lithology Determination  Sandstone vs. Limestone  Silicon Activation for gravel pack evaluation  Oxygen Activation  Water flow inside and outside casing  Stationary reading for water flow velocity calculation  Porosity Determination  From RTMD y RIN  Tight versus identification of gas   Chi ModelingSM  Generation of Triple-Combo data using RMT data and Neural Net  Repairing Open Hole logs © 2013 Halliburton. All Rights Reserved.

MF - 75

C/O

Σ

Σ C/O

C/O C/O

Σ

© 2013 Halliburton. All Rights Reserved.

MF - 76

Σ

Best Solution for Estimating Fluids Saturations in Completed Wells © 2013 Halliburton. All Rights Reserved.

MF - 77

Production Diagnostics & Surveillance Production Logging Tools “PLT” © 2013 Halliburton. All Rights Reserved.

MF - 78

Production Logging Environment: 1

2

Heel Injection String

Toe ToeInjection InjectionString String

From: 1. Wikimedia Commons 2. M. Bedry & J. Shaw; SPE 154760 - Using a new Intelligent Well Technology Completions Strategy to Increase Thermal EOR Recoveries–SAGD Field Trial © 2013 Halliburton. All Rights Reserved.

MF - 80

Production Logging Environment: 1

2

Heel Injection String

© 2013 Halliburton. All Rights Reserved.

MF - 81

Toe ToeInjection InjectionString String

Production Logging Tools Production Logging (DIAGNOSTIC AND SURVEILLANCE) • PL encompasses logging techniques to measure dynamic wellbore-reservoir parameters. PL includes a flow measuring device. • PL can be done during the entire well life cycle: primary, secondary, EOR. It is also used routinely in injection wells.

Tools may be run on non-conducting slickline or coiled tubing © 2013 Halliburton. All Rights Reserved.

MF - 82

Production Logging Tools Production Logging (DIAGNOSTIC AND SURVEILLANCE) • PL encompasses logging techniques to measure dynamic wellbore-reservoir parameters. PL includes a flow measuring device. • PL can be done during the entire well life cycle: primary, secondary, EOR. It is also used routinely in injection wells.

Tools may be run on non-conducting slickline or coiled tubing © 2013 Halliburton. All Rights Reserved.

MF - 83

Sweep Efficiency Monitoring Injector

Production

Observation/ Production

Observation/ Production

Production

Idealized water flood front – homogenous reservoir

Injector

Complex flood path with potential early water break through – complex reservoir structures, fractures, permeability relationships and fluid interactions

© 2013 Halliburton. All Rights Reserved.

MF - 85

Production Logging Conformance: • Sweep efficiency in both secondary and EOR "floods" is enhanced by conformance technology. • Production logging can identify any variation in injection and production flows in the perforated zones. • Conformance technology is applied to seal or reduce the formation permeability in the perforations and/or the near-wellbore region with the highest flow rates to allow more of the injected fluid to divert into lowerpermeability intervals in the injection zone.

 Sweep efficiency can be substantially improved by flow diversion.

© 2013 Halliburton. All Rights Reserved.

MF - 86

Production Logging Main Objectives:  Monitor Reservoir Production Performance  Evaluate Treatment / Stimulation Effectiveness  Diagnose Completion Problems  Undesired Fluid (Water / Gas) Entry  Tubular Leaks  Zonal Production Contribution

© 2013 Halliburton. All Rights Reserved.

MF - 87

Production Logging Main Objectives:  Monitor Reservoir Production Performance  Evaluate Treatment / Stimulation Effectiveness  Diagnose Completion Problems  Undesired Fluid (Water / Gas) Entry  Tubular Leaks  Zonal Production Contribution From: 3. SPE: 122199 Application of an Advanced Dynamic-Underbalance Perforating System for Improved Oil Production in Development Wells © 2013 Halliburton. All Rights Reserved.

MF - 88

PL Typical Logging String

© 2013 Halliburton. All Rights Reserved.

MF - 89

PL TOOLS - SPINNERS

© 2013 Halliburton. All Rights Reserved.

MF - 90

PL - Interpretation Velocity Correction 1.00

Turbulent Flujo Flow Turbulento

0.90 0.80

U/Umax r/rl

0.70 0.60 0.50 0.40

Flujo Laminar Laminar Flow

0.30 0.20 0.10 0.00 -1.0

-0.8

-0.6

-0.4

-0.2

0.0

0.2

0.4

0.6

0.8

1.0

U/Umax r/ri

Vf VapVcf

•

Corrected linear velocity equation:

•

takes into account tool position, flow profile, and spinner response

© 2013 Halliburton. All Rights Reserved.

MF - 99

Planning a Production Logging Program  Is Well Flowing in a Steady State?  Wait Until Stabilization Occurs  Change Choke Size  Multiple Spinner Passes to Determine Correct VA  30, 60, 90, 120 Up and Down  Stationary Measurements to Confirm Holdup / Temperature and Pressure Readings  Shut-in Passes for Buildup Pressure Readings  Determination of Thief Zones  In-Situ Calibration of Spinners/ Holdup Devices

© 2013 Halliburton. All Rights Reserved.

MF - 100

PL - Interpretation Holdup Yw

Yg Yo

The holdup of a phase is the volume fraction occupied by that phase at downhole conditions. By definition:

© 2013 Halliburton. All Rights Reserved.

Yw  Yo  Yg  1

MF - 101

PL - Interpretation

Gas-Liquid Flow Regimes

© 2013 Halliburton. All Rights Reserved.

MF - 102

Why Do We Need All These Tools?  Minimum Needed for 90 % of Production Logging Jobs     

Spinner (Flowmeter) Temperature Pressure 1- Holdup Device for Single / Two Phase Flow 2 -Holdup Devices for Three Phase Flow at Downhole Conditions

 Special Tools for Improved Results     

RMT-E TMD3D GHT Full-Bore Spinner Diverter Spinner

© 2013 Halliburton. All Rights Reserved.

MF - 103

Production Logging Analysis Programs  Fluid Velocity  Fullbore and In-line Spinner (Continuous)  Diverter Spinner and/or Radioactive Tracer (Stationary)  Single, Two and Three Phase Flow Analysis  Comprehensive Continuous Analysis of Production Data  Holdups  Pressure, Volume, and Temperature Correlations  Several Slip Velocity Options  Flow Rates at Both Downhole and Surface Conditions  Zonal Averaging and Incremental Production  Complete Wellbore Diagrams

© 2013 Halliburton. All Rights Reserved.

MF - 104

Basic Production Logs Raw Data CS8

SR8 150 -10

-150 CS7 -150

150 -10

CS5

-150

186

188 PRESSURE

3000

3200 GAMMA RAY

0

150 -10

150

-150 PERF

PERF

PIPE

PIPE

CMNT

CMNT

FORM

FORM

D

X500

CS3

-150 CS2 -150 FLUID DENSITY 0.2

10 SR4

150 -10 150 -10

SR3 SR2

150 -10

10 10 10

SR1

CS1 1.2 -150

10 SR5

150 -10 CS4

TEMPERATURE

10 SR6

CS6 -150

10 SR7

150 -10

10

 Temperature Logs Can Identify Fluid Flow and Entry Into the Casing  Spinner Logs Can Detect Fluid Entry and Exit Points Inside Casing

C

 Holdup Devices Can Also Indicate Fluid Entry

B

X600

A

© 2013 Halliburton. All Rights Reserved.

MF - 105

PL Interpretation

© 2013 Halliburton. All Rights Reserved.

MF - 106

PL Interpretation

Flowmeter Electronics

© 2013 Halliburton. All Rights Reserved.

MF - 107

PL Interpretation

Flowmeter Electronics

© 2013 Halliburton. All Rights Reserved.

MF - 108

PL Interpretation Ideal Spinner Response – No Flow 6 5 4 3 2 1

Spin Rates Spin Rate Rev/Sec rev/sec

0 -1 -2

Va = -1.49 Slope = .0381 Quality = .99955

-3 -4 -5 -6 -150

-100

-50

0

Cable CableSpeed Speed feet/minute Ft / Minute feet/m inute

© 2013 Halliburton. All Rights Reserved.

MF - 109

50

100

150

PL Interpretation Actual Spinner Response – No Flow 6 5 4

Vth (-) = -8.70 Slope (-) = .0419 Q uality (-) = .99998

3 2 1

Spin Rates Spin Rate rev/sec Rev/Sec

0 -1

Vth (+) = 4.59 Slope (+) = .0407 Quality (+) = .99975

-2 -3 -4 -5 -6 -150

-100

-50

0

Cable Speed Cable Speed feet/m inute Ft / Minute

© 2013 Halliburton. All Rights Reserved.

MF - 110

50

100

150

PL - Interpretation Velocity Correction

N Re 

DVap 



© 2013 Halliburton. All Rights Reserved.

MF - 111

PL - Interpretation Single phase flow rate determination Vap

VCF = 0.83

Q  Vf  A

Vf = VCF x Vap

Reynolds Number

VCF=VCF’

VCF’

Q © 2013 Halliburton. All Rights Reserved.

MF - 112

PL - Interpretation

© 2013 Halliburton. All Rights Reserved.

MF - 113

PL - Interpretation QC data Select passes Calibrate spinner Enter PVT Select reference inputs Select appropriate correlation Select zones

Note: Graphs shown for illustrative purposes only, and not from the same well © 2013 Halliburton. All Rights Reserved.

MF - 114

PL - Interpretation QC data Select passes Calibrate spinner Enter PVT Select reference inputs Select appropriate correlation Select zones Depth Z ft -11000

Q B/D

QZI B/ D

1000-5500

500-7000

QZT B/ D

QZTR 500-0.2

1.2

6200

6514 B/D 6300

5121 B/D

78.6%

6400

6500

6600

1392 B/D

1392 B/D

21.4%

6700

Note: Graphs shown for illustrative purposes only, and not from the same well © 2013 Halliburton. All Rights Reserved.

MF - 115

CHALLENGES – Horizontal well  Effectiveness and fracture performance  Well Trajectory influence on holdup and phase velocity  Generally less pre-production per well evaluation compare to traditional reservoir  To quantify stage performance in complex flow regime requires circumferential arrays sensors coverage without disturbing flow regime  Conveyance Challenges

© 2013 Halliburton. All Rights Reserved.

MF - 116

Why Array Sensors / Tools?

From: 4. “Sondex UltraWireTM Production Logging User Guide Version 1.0 © 2013 Halliburton. All Rights Reserved.

MF - 117

Converting Holdup Calculation into Imaging

gas has entered the well © 2013 Halliburton. All Rights Reserved.

continuous stream of oil at the top

oil phase exclusively flowing over the peak MF - 118

oil bubbles passing through the trough

Vertical Production Logging Tool Combination GR/CCL

TMDL ,RMT-E or WFL

Inclinometer Pressure Temperature Hydro Gas Holdup Tool

 Flowmeters, Holdup , Temperature /Pressure Are Required to Provide Full Analysis  Various Types of Spinners Are Available to Quantify Fluid Flow Rates  Pulsed Neutron Logs Can Also Provide Quantitative Water Flow Rates

Radioactive Fluid Density Fullbore Flowmeter Basket Flowmeter or Both

© 2013 Halliburton. All Rights Reserved.

MF - 119

Horizontal Production Logging Tool Combination Gamma Ray

Flex Joint

Collar Locator

Telemetry

Inline Flow meter

Temperature

Pressure

Full-bore Flow meter

Continuous Flow meter

Hydro

GHT SAT

CAT

Density

Tools are rated for 15000 PSI and 350 F On E Line / Slick Line / Coil tubing © 2013 Halliburton. All Rights Reserved.

MF - 120

RAT

PL – ARRAY TOOLS CAT Capacitance Array Tool

RAT Resistivity Array Tool

SAT

Spinner Array Tool

© 2013 Halliburton. All Rights Reserved.

MF - 121

Typical Horizontal well PL Tool String

Total Length: 48.74 ft Total Weight: 209.10 lbs Max. O.D.: 2.13”

© 2013 Halliburton. All Rights Reserved.

MF - 122

PL - Interpretation

© 2013 Halliburton. All Rights Reserved.

MF - 123

PL - Interpretation

© 2013 Halliburton. All Rights Reserved.

MF - 124

PL - Interpretation

© 2013 Halliburton. All Rights Reserved.

MF - 125

Converting Holdup Calculation into Imaging PLAY

gas has entered the well © 2013 Halliburton. All Rights Reserved.

continuous stream of oil at the top

oil phase exclusively flowing over the peak MF - 126

oil bubbles passing through the trough

Production Logging Analysis % HOLDUP 100

0

PERF

PERF

PIPE

PIPE

WATER

CMNT

CMNT

OIL

FORM

FORM

0

STB / DAY 7500 WATER OIL

0

STB / DAY 7500 WATER

0

STB / DAY 4000 WATER

OIL

OIL

 Continuous Analysis of Production Logging Data

D

 Complete Wellbore Diagrams

X500

1190 280

C

 Calculate Flow Rates at both Downhole and Surface Conditions

1150 1310

B

 Zonal Averaging and Incremental Production/Injection

1320

1380 X600

 Single, Two and Three Phase Flow estimates

A

© 2013 Halliburton. All Rights Reserved.

MF - 127

Production Logging Zonal Contribution:

© 2013 Halliburton. All Rights Reserved.

MF - 128

Armada® FST and Production Logging Combination Tool Collar Locator

Telemetry

Gamma Ray

Flex Joint

Inline Flow Meter

Fullbore Flow Meter

Continuous Flow Meter

Temperature

Armada® FST

SAT

GHT

Density

CAT

Tools are rated for 15,000 psi and 350°F © 2013 Halliburton. All Rights Reserved.

Pressure

MF - 134

Hydro

RAT

CONVENTIONAL CORE RECOVERY Loss of reservoir fluids due to reduction in pressure as core is recovered.

Loss of the most important part of reservoir system …..

The Hydrocarbons © 2013 Halliburton. All Rights Reserved.

MF - 135

CONVENTIONAL CORE RECOVERY Loss of hydrocarbon from reservoir to surface conditions continues with time.™

Objective : Develop a time and cost effective system that capture reservoir rock and fluid volumes for detailed analysis.™ © 2013 Halliburton. All Rights Reserved.

MF - 136

Wireline Rotary CoreVault™ System

Halliburton HRSCT-B Rotary Wireline Core Instrument, Drill Bit Section

© 2013 Halliburton. All Rights Reserved.

MF - 137

Wireline Rotary CoreVault™ System Finished Tube Returns From First Job Transfer Manifold

Compensation Spring

Transport Cap

© 2013 Halliburton. All Rights Reserved.

MF - 138

Wireline Rotary CoreVault™ System Exclude Contamination of Borehole Drilling Fluid Drilling Mud

© 2013 Halliburton. All Rights Reserved.

CoreVault Recovery

MF - 139

Wireline Rotary CoreVault™ Transport

Overpack Transport Safety Systems © 2013 Halliburton. All Rights Reserved.

HRSCT-P Safety System MF - 140

Primary vs. Enhanced Oil Recovery

Production - 1000 bbls/day of Oil

Primary vs. Enhanced Oil Recovery Example 3,000 2,500

Primary Recovery

2,000

Injection

1,500

EOR

1,000 Oil Production

500 0

0

© 2013 Halliburton. All Rights Reserved.

10

20 Years

MF - 141

30

40

Production Management Khalda Offset Concession Wireline Formation Tester Analysis Qasr-1X and Qasr-2 Lower Safa Formation Pressure versus Depth -12100 Qasr-1x

-12200

Qasr-2

Qasr-1X pressures recorded by Schlumberger MDT tool.

-12300

Qasr-2X pressures recorded by Halliburton SFT tool.

Gas Gradient 0.119 psi/ft 0.28 gm/cc

Subsea Depth (feet)

-12400 -12500

Qasr -2x GasColumn 692 ft

Qasr -1x GasColumn 680 ft

-12600 Two service companies used for formation pressure testing. These companies use different testing tools, gauges and depth control procedures.

-12700 -12800 -12900 -13000 -13100

… estimates an increased OOIP estimate exceeding 200 million barrels

-13200 5650

Sources: Schlumberger MDT, Halliburton SFT December 22, 2003

© 2013 Halliburton. All Rights Reserved.

-12885 SS 13562 MD

Water Gradient 0.456 psi/ft 1.05 gm/cc

-12925 SS 13580 MD

5700

5750

5800

5850

5900

5950

6000

6050

6100

Pressure (psia) B Johnson

MF - 144

288 °C  550 °F

Production Management

.1er Foro del Activo Integral Samaria Luna:: Retos y Desafíos en la Evaluación de Pozos con Inyección de Vapor en el Proyecto Samaria-Neógeno © 2013 Halliburton. All Rights Reserved.

MF - 145

Production Management 188°C

299°C

15-Jun-2010 Fluyendo Verde 12-May-2010 Remojo Morado

Presion Original Estimada RDT

12-Dic-2011 Remojo 30-Nov-2011 Inyeccion Rojo .1er Foro del Activo Integral Samaria Luna:: Retos y Desafíos en la Evaluación de Pozos con Inyección de Vapor en el Proyecto Samaria-Neógeno © 2013 Halliburton. All Rights Reserved.

MF - 146

Completion & Borehole Integrity Diagnostics Cement Evaluation & Casing Inspection

© 2013 Halliburton. All Rights Reserved.

MF - 148

Casing Inspection & Cement Evaluation Logs Objectives:  Find Holes, Splits, or Deformities in Pipe / Casing  Evaluation of Zonal Isolation and Detection of channels &/or microannulus within the Cement  Both Internal and Total Pipe Measurements Available depending on tool type  Log Types  Mechanical Calipers  Pipe Inspection  Acoustic  Cement Evaluation  Ultrasonic  Both Pipe Inspection & Cement Evaluation  Electromagnetic Phase Shift  Pipe Inspection  Flux Leakage / Eddy Current  Pipe Inspection © 2013 Halliburton. All Rights Reserved.

MF - 149

Casing Inspection & Cement Evaluation Tools  CAST-F/M - Circumferential Acoustic Scanning Tool  Cement Evaluation and Casing Inspection

 CBL/VDL - Cement Bond Log / Variable Density Log  Cement Evaluation

 MIT - Multi Finger Imaging Tool  Casing Inspection

 MTT - Magnetic Thickness Tool  Casing Inspection

© 2013 Halliburton. All Rights Reserved.

MF - 150

T

Cement Evaluation Mud

Cement

Cement Bond Log “CBL” Variable Density Log “VDL”

Formation

Casing

Casing

T

 One Acoustic Transmitter (20 khz) + Receivers at 3 & 5 ft spacing  Transmit an Omni-directional acoustic signal for detecting the absorbed acoustic energy level of the Casing, Cement and Formation  The received Signal is Omni-directional

Cement

 Measurements: R3’

R5’

© 2013 Halliburton. All Rights Reserved.

 Travel Time (TT): Time taken for the signal to travel from the Transmitter to the receiver through the Casing, Cement and Formation  Acoustic Signal Amplitude: The acoustic energy level (amplitude) received by the first arrival  Variable Density (VD): The form of the acoustic signal received by the 2nd receiver MF - 151

CBL/VDL Operational Considerations  Tool has to be run Centralized Formation Casing

 High density borehole fluid may attenuate the Acoustic signal  Is important to calibrate the tool response in Free Pipe

Mud

 Available Tool Sizes:    

© 2013 Halliburton. All Rights Reserved.

MF - 152

1” 11/16 std y radial 2” 3/4 radial 3” ¼ std 3” 5/8 std

Travel Time of various Materials Material             

Travel Transit Time (sec/ft)

Sandstone Limestone Dolomite Salt Anhydrite Water (Fresh) Water (100,000 ppm NaCl) Water (200,000 ppm NaCl) Oil Air Casing (steel) Water Base Mud Cement

© 2013 Halliburton. All Rights Reserved.

55.5 47.6 43.5 67.0 50.0 200.0 189.0 182.0 222.0 919.0 57.0 167.0 90.0-160.0

MF - 153

Acoustic Signal Mode of Travel Cement

Mud

Mud/Fluids 189-208 μsec/ft

Casing

Formation

Casing

T

57 μsec/ft

Cement 100 μsec/ft

Formation 40-140 μsec/ft

R3’

Composite R5’

© 2013 Halliburton. All Rights Reserved.

MF - 154

Variable Density Log (VDL) 5’ Receiver Poor Bond Good Bond Transmitter

Depth

T (µsec)

1/23/2014 © 2013 Halliburton. All Rights Reserved.

MF - 155

CBL/VDL Interpretation 4 Basic Cementing conditions Transmitter

3 ft Receiver

5 ft Receiver

Free Pipe

© 2013 Halliburton. All Rights Reserved.

Transmitter

Transmitter

Transmitter

3 ft Receiver

3 ft Receiver

3 ft Receiver

5 ft Receiver

5 ft Receiver

5 ft Receiver

Good Casing-to-Cement Bond MF - 156

Partial Cementation with Channels

Good Cement Bond

CBL/VDL Interpretation GAMMA RAY 0

AMPLITUDE 150

TRAVEL TIME 200

300

0 CCL

Y50

Free Pipe No Cement

Y75

© 2013 Halliburton. All Rights Reserved.

MF - 157

100 AMPLIFIED AMPLITUDE 0 10

CBL WAVEFORM -20

20

CBL/VDL Interpretation Good Cement-to Casing and Cement-to-Formation Bond

© 2013 Halliburton. All Rights Reserved.

MF - 158

CBL/VDL Interpretation Partial Cementing

© 2013 Halliburton. All Rights Reserved.

MF - 159

Cement Evaluation & Casing Inspection  CAST-F/M – Rotating Acoustic measurements  Image Mode  Amplitude  Travel Time  Travel Time Corrected for Eccentering

 Cased Hole Mode  Acoustic Impedance  Casing Thickness  Cement Evaluation

© 2013 Halliburton. All Rights Reserved.

MF - 160

Two CAST Tool versions  CAST-F (FastCast 7c cable)  3 5/8” OD  Multi-conductor cable and high speed telemetry  Faster logging speed over legacy ultrasonic tools  Application 5” to 22” casing/riser  Programmable for 100% Azimuthal coverage  CAST-M (mono conductor CAST)  2 ¾” OD tool – with 3 1/8” transducer head  Slim hole – evaluate 4 ½” to 9 5/8” casing  Programmable for 100% Azimuthal coverage  1c cable traditional cased hole units & rig less operations  Down hole processing and tool memory • Transmit down hole computed data up the 1c e-line • Waveform data stored in downhole memory • Fast memory download when tool is retrieved © 2013 Halliburton. All Rights Reserved.

MF - 161

CAST Operational Considerations Liquid Filled Borehole Mud Weight Internal Scale Tool Centralization

© 2013 Halliburton. All Rights Reserved.

MF - 162

CAST-F Measurement Modes  Cased Hole Mode: 100 Azimuthal Shots 100 % Coverage @ 2, 4 or 12 Samples/ft  Image Mode: (OH or CH) 200 Azimuthal Shots 100 % Coverage @ 60 Samples/ft

Pressure Compensation & Fluid Cell Section

Scanner Head Section

© 2013 Halliburton. All Rights Reserved.

MF - 163

CAST-F/M Measurements  Borehole fluid travel time  Continuous measurement on all logging passes

 Inclination & Relative Bearing  Orientation of data to high side of casing

 Casing radius  Two way time of flight and fluid travel time

 Casing thickness  Frequency of reflected signal

 Acoustic Impedance  Cement Sheath Evaluation © 2013 Halliburton. All Rights Reserved.

MF - 164

Advanced Cement Evaluation Software “ACE”  Uses statistical variation to help determine if the material behind the casing is either fluid or solid  Cement has a high variation  Liquids and Gases have a low variation

 In other words  Wiggles  Good Cement  Straight lines  Bad (or no) Cement

 ACE process can also be applied on competitor's data

© 2013 Halliburton. All Rights Reserved.

MF - 165

CAST-F/M

Black

5

Acoustic Impedance Values

Dark Brown

4

Z =ρ× V Z: Acoustic Impedance ρ: Material Density V: Acoustic Velocity Material Water Gas Steel (Casing) Mud 12 ppg Mud 15 ppg Mud 17 ppg Foam Cement G 9 ppg (250 psi ) Foam Cement G 9 ppg (1000 psi) Cement 13 ppg (500 psi) Cement 13 ppg (2000 psi) Cement 16.5 ppg (500) Cement 16.5 ppg (2000 psi) © 2013 Halliburton. All Rights Reserved.

Acoustic Impedance 1.50 0.10 46.00 2.16 2.70 3.06 2.19 2.69 3.37 4.42 4.38 5.62

Light Brown

3

Tan Cement

2

1

Water

Drilling Mud

+ Free Gas

0

=

Blue

Foam Cement Red Green

MF - 166

Typical Presentation of Cement Evaluation Log

CBL Amplitude Cement-to-Casing Map

Amplified CBL Amplitude

Average Impedance

CCL

GR

VDL

Travel Time © 2013 Halliburton. All Rights Reserved.

MF - 167

CAST-F Example Showing Channel behind pipe starting @ 3227 till the top

© 2013 Halliburton. All Rights Reserved.

MF - 168

GAMMA 0

AMPLIFIED CBL AMPLITUDE WAVEFORM 0 10 WMSG AMPLITUDE 20 0 70 -20

100 ECENTRICITY

0

1.0 TRAVEL TIME

260

Foam Cement Example (8 lb / gal)

160

XX00

XX50

© 2013 Halliburton. All Rights Reserved.

MF - 169

AVERAGE Z 10 0 IMPEDANCE MINIMUM Z IMAGE 10 0 ZP MAXIMUM Z 6.15 10 0 0

GR 0 100 ECCE 0 1 AVG Z 10 0

SEGMENTED IMPEDANCE CURVES

A1 A2 A3 A4 IMPEDANCE VARIANCE 0 6.15 0 0.6 A5

Foam Cement Example (8 lb / gal) ACE Segmented Curves

B1 B2 B3 B4 B5

C1 C2 C3 C4 C5

D1 D2 D3 D4 D5

E1 E2 E3 E4 E5

F1 F2 F3 F4 F5

High Activity = Cement XX00

Variance is a measure of Activity

XX50

© 2013 Halliburton. All Rights Reserved.

MF - 170

Low Activity = Fluids/Gas

G1 G2 G3 G4 G5

0-5 SCALE

H1 H2 H3 H4 H5

I1 I2 I3 I4 I5

ACE CBL Collar Responses ACE applies the variance method to the CBL waveform.

Free Pipe GAMMA 0 150 ECEN 0 1

AMPLIFIED WMSGD AMPLITUDE WMSG CBL DERIVITIVE OR 0 10 AMPLITUDE CBL WAVEFORM VARIANCE 0 70 -20 20 0 10 0

Free Pipe to Bonded Pipe

Examination of the chevron collar response is the key. Microannulus

© 2013 Halliburton. All Rights Reserved.

MF - 171

WMSGT CBL TOTAL 20

CAST ACE

AMPLITUDE 0 100 AMPLIFIED AMPLITUDE 0 10 FCBI 1 0 FCEMBI 1 0

GR 0 100 ECCE 0 1 AVG Z 10 0

WMSG -20

Both the Impedance and Variance to Evaluate Cement bonding

WMSGT 20 0

IMPEDANCE VARIANCE CEMENT 20 0 6.15 0 0.6 0 1

Cement bond to both pipe and formation XX00

XX50

Free pipe © 2013 Halliburton. All Rights Reserved.

MF - 172

CAST-F/M Casing Inspection Software  Correction for Tool Eccentricity  Segments and Images  Three-Dimensional Images  Joint and Depth Listings  Top, Bottom and Length of Joints  Minimum, Maximum and Average • Internal Radius and Thickness

 Excel Spreadsheets and Summations  Allow monitoring of Damage over time

 Complete Report includes Summations and Images © 2013 Halliburton. All Rights Reserved.

MF - 173

Marine Riser Inspection 19.25” ID 22” OD

ECCEN EC C ENTR TR ICITY IC ITY CO REC C OR RR ECTED TR AVEL T TIM E A MPLITU TR AVEL T TIM E TRAVEL IME AM PLITUD E IME 5455 15 85 1585 60 6000 00 660 6600 0 1154 5455 15 158 855 1154

O VA LITY 0 0.2 ECCENTRICITY EC CENTRIC ITY 0 1.0

X050

CAST shows the welded seam from the manufacturing process

X 100

© 2013 Halliburton. All Rights Reserved.

MF - 174

Packer Damage CAST-F Raw Data 7” 26 lb. Casing

© 2013 Halliburton. All Rights Reserved.

MF - 175

CAST-F 3-D Image Packer Damage

ECCENTRICITY CORRECTED TRAVEL TIME

AMPLITUDE 3000

5000

425

(D)

(C)

(B)

© 2013 Halliburton. All Rights Reserved.

MF - 176

500

GAMMA RAY GAMMA 0 200 200 IMPEDANCE 10 10 0 ECCENTRICITY 0 1.0

AMP AMP AMPLITUDE 0 10 10 AMPLITUDE AMPLITUDE 0 60 60 CAST BOND 1 1 00 - 20

CAST-F & ACE Processing Y650

Detects Separated Casing Y700

Y750

© 2013 Halliburton. All Rights Reserved.

MF - 177

CBL CBL WAVEFORM

1 TOTAL TOTAL CBL CBL WAVEFORM 250 1 250 0 20 0 20

IMPEDANCE MAP

100 6.15

0

CAST-F & ACE Processing

DEVIATION

25 25 GAMMA RAY RAY 0 200 200 OVALITY OVALITY 0 0.5 ECCENTRICITY ECCENTRICITY 0 1.0

PIPE SHAPE

Y650

Detects Separated Casing Y700

Y750

© 2013 Halliburton. All Rights Reserved.

AVERAGE THK THK AVERAGE RAD AVERAGE 0.217 0.417 0.417 2.933 2.933 3.433 MINIMUM MINIMUM THK MINIMUM MINIMUM RAD RAD PIPE 0.217 0.417 0.417 2.933 3.433 PIPE PIPE RADIUS RADIUS PIPE THICKNESS THICKNESS 2.933 MAXIMUM RAD 11 THK 1 100 100 MAXIMUM THK 100 OUTSIDE 0.417 3.433 0.217 0.217 0.417 2.933 2.933 3.433 2.933 0.417 0.217 INSIDE

MF - 178

Casing Evaluation Logs X200

CAST-F Inspection Log

X250

 Ultra-Sonic Rotating Transducer for 360o Coverage X300

 Internal Radius and Thickness Profiles X350 DEPTH

ECCENTRICITY

WELLBORE

0.5 0 OVALITY 0.5 0

CASING

DEVIATION 10.0

OUTSIDE

0

© 2013 Halliburton. All Rights Reserved.

CASING PROFILE

MF - 179

4.5

5.5 4.6

5.2

DIAMETER CURVES AVERAGE

INTERNAL DIAMETER

0.2 0.4 0.15 THICKNESS CURVES AVERAGE

MAXIMUM

MAXIMUM

MINIMUM

MINIMUM

0.45

CASING THICKNESS

CAST-F & ACE Processing 7” Liner

There is a single (large) hole with thin wall areas adjacent to the hole

© 2013 Halliburton. All Rights Reserved.

MF - 180

CASE Cased-Hole Mode

Determination of casing problems with both internal radius and thickness measurements

AVRADN -.25 .25 MAXRADN PIPE -.25 .25 AMPLITUDE MINRADN .25 70 135 -.25

GR 0

100 ECCE

0

1 OVAL

0

.2

X500

X550

© 2013 Halliburton. All Rights Reserved.

AVTHIKN -.25 .25 NORMALIZED NORMALIZED MAXTHIKN PIPE PIPE -.25 .25 MINTHIKN RADIUS THICKNESS .25 -.25 -.25 .25 -.25 .25

Major Casing Damage

MF - 181

Cased-Hole Mode 3-D Images Casing Damage 3-D View

© 2013 Halliburton. All Rights Reserved.

MF - 182

CAST-M Wellsite 4 ½” Casing Inspection Data Collar leak

Casing Swelling from C Capsule Perforating Guns

Damage from Milling Packer

© 2013 Halliburton. All Rights Reserved.

MF - 183

CAST-F

AVRADN AVTHIKN -.25 .25 -.25 .25 NORMALIZED NORMALIZED MAXRADN MAXTHIKN PIPE PIPE PIPE -.25 .25 -.25 .25 AMPLITUDE RADIUS THICKNESS MINRADN MINTHIKN 800 1300 -.25 .25 -.25 .25 -.25 .25 -.25 .25

GR 100 ECCE 0 1 OVAL 0 .2

0

Cased Hole Mode Standard Casing

Liner Top Determination of casing problems with both internal radius and thickness measurements

X200

Standard Casing © 2013 Halliburton. All Rights Reserved.

MF - 184

CAST-F

GR 0 100 ECCENTRICITY 0 1.0 OVALITY 0 .2

AVE. RADIUS 4 6 MIN. RADIUS 6 PIPE CORRECTED 4 PIPE CORRECTED AMPLITUDE TRAVEL TIME MAX. RADIUS AMPLITUDE TRAVEL TIME 6 300 1000 1200 53 63 4 1050 84 89

Image Mode

RESCALE SHOWING LINER OVERLAP

X200

© 2013 Halliburton. All Rights Reserved.

MF - 185

CAST-F Image Mode High Resolution Casing Inspection

© 2013 Halliburton. All Rights Reserved.

MF - 186

CAST-F Cement Evaluation

GR 0 ECCE 0 1 OVAL 0 .2 MFTT 220 170

100 TT 260 160

AMPLITUDE 0 100 AMPLIFIED AMPLITUDE 0 10

WMSG -2500

AVERAGE IMPEDANCE IMPEDANCE 2500 10 6.15 0 0

Good Bond

Liner Top High Eccentricity X200

Notice the “strange” log response on the impedance map © 2013 Halliburton. All Rights Reserved.

MF - 187

CASE  Determination of casing problems with both internal radius and thickness measurements

AVRADN -.25 .25 MAXRADN PIPE -.25 .25 AMPLITUDE MINRADN 800 1300 -.25 .25

GR 0 100 ECCE 0 1 OVAL 0 .2

Standard Casing

Liner Top X200

Standard Casing © 2013 Halliburton. All Rights Reserved.

MF - 188

NORMALIZED PIPE RADIUS -.25

AVTHIKN -.25 .25 MAXTHIKN -.25 .25 MINTHIKN .25 .25 -.25

NORMALIZED PIPE THICKNESS -.25 .25

Image Mode

GR 0 100 ECCENTRICITY 0 1.0 OVALITY 0 .2

AVE. RADIUS 4 6 MIN. RADIUS 4 6 PIPE PIPE CORRECTED CORRECTED AMPLITUDE TRAVEL TIME MAX. RADIUS AMPLITUDE TRAVEL TIME 4 6 1000 1200 53 63 300 1050 84 89

Rescale Showing Liner Overlap

X200

© 2013 Halliburton. All Rights Reserved.

MF - 189

High Resolution Casing Inspection

© 2013 Halliburton. All Rights Reserved.

MF - 190

Pull Out Casing Vs. FASTCAST 3D Image

© 2013 Halliburton. All Rights Reserved.

MF - 191

CASTF- Log Image Mode 2D Image Example of Parted Casing

© 2013 Halliburton. All Rights Reserved.

MF - 192

CASTF- Log Image Mode 3D Image Example of Broken Casing

© 2013 Halliburton. All Rights Reserved.

MF - 193

F-CASTV - CastCase Procesing Fractured Casing Applying Pressure

© 2013 Halliburton. All Rights Reserved.

MF - 194

CASTF- Log Image Mode 3D Image Perforated Interval

© 2013 Halliburton. All Rights Reserved.

MF - 195

CASTF- Log Image Mode 3D Image Perforated Interval

© 2013 Halliburton. All Rights Reserved.

MF - 196

MIT Multi-Finger Imaging Tool GE/Sondex Technology

 Multi Finger Mechanical Caliper  Tool OD Number of Arms  1 11/16”  2.75”  3.9”

24 40 60

 Internal Inclinometer for orientation of data with respect to high side  Accuracy 0.03”  Deployment  E-line or Slick Line (memory) © 2013 Halliburton. All Rights Reserved.

MF - 197

MIT Multi-Finger Imaging Tool  Limitations  ID measurement only  True ID measurement can be affected by scale

© 2013 Halliburton. All Rights Reserved.

MF - 198

MIT Multi-Finger Imaging Tool  Simple Mechanical Measurement  Different Size Tools with Varying Number of Arms to Fit Tubulars  Inside Casing or Tubing Defects Only

© 2013 Halliburton. All Rights Reserved.

MF - 199

Example MIT Log – Split Casing  Problem: Failed pressure test on 4.5” OD casing  proposal: ran 40-finger MIT to inspect for damage  field logs detected damage, but unclear to extent and dimensions

 solution: MIT data post-processed; 3D visualization depicted split casing

3D visualization from MIT data

MIT 40 caliper log damage seen on pulled casing

© 2013 Halliburton. All Rights Reserved.

MF - 200

MTT Magnetic Thickness Tool GE/Sondex Technology

 Electro-magnetic measurement of casing wall thickness  phase shift (velocity)  attenuation (amplitude)

 1 11/16” OD  2 7/8” Tubing through 7” casing

 12 Radial Sensors on bow springs  100% Coverage in 5” csg or smaller

 Sensitivity/Defect Resolution  3/8” diameter defect - 50% wall thickness, 35% metal loss  3/4” diameter defect - 20% wall thickness, 20% metal loss

 Internal Inclinometer for orientation of data with respect to high side  Combinable with MIT Multi Finger Imaging Tool  Deployment  E-line or Slick Line (memory) © 2013 Halliburton. All Rights Reserved.

MF - 201

MTT Magnetic Thickness Tool  Limitations  Wall Thickness measurement  +/- 15% in undamaged pipe

 Caliper measurements required to determine if metal loss is internal or external

© 2013 Halliburton. All Rights Reserved.

MF - 202

MTT Magnetic Thickness Tool Measures wall thickness, therefore can see both internal & external corrosion Detects pitting and gradual metal loss Run in combination with MIT for detailed pipe analysis

© 2013 Halliburton. All Rights Reserved.

MF - 203

Perforation Techniques Considerations

© 2013 Halliburton. All Rights Reserved.

MF - 204

Perforation Sequence Perforating Charge Prior To Detonation

© 2013 Halliburton. All Rights Reserved.

Initial Jet Formation Penetrating Steel

MF - 205

Perforation Sequence Complete

Environment:

Perforation Techniques Considerations

Heel Injection String

© 2013 Halliburton. All Rights Reserved.

MF - 206

Toe ToeInjection InjectionString String

History of Perforation Techniques  Mechanical Tools  Bullet Guns - 1930’s  Shaped Charges - 1940’s  Through-Tubing Guns - 1950’s  Tubing Conveyed Perforating - 1970’s  Extreme Overbalance Perforating - 1990’s  Hydraulic Perforators Late 60’s & Mid 90’s  EOBP with Propellant Jacket - late 1990’s to present

© 2013 Halliburton. All Rights Reserved.

MF - 207

Cement

Casing

Perforation Techniques Considerations

Perforation Tunnel Reservoir Rock

Perforation Depth

© 2013 Halliburton. All Rights Reserved.

MF - 208

Which Perforation Technique ? The technique that provides higher wellbore to formation contact with the least amount of damage to the created perforations

 Overbalanced  Balanced  Underbalanced  Extremely overbalanced  Focused energy  Hydraulic

© 2013 Halliburton. All Rights Reserved.

MF - 209

Perforation System Geometry (Idealized after Bell, et al, 1995) Damaged Zone Diameter

Casing

Cement Sheath Damaged Zone Diameter Perforation Diameter Perforation Spacing (Dependent on Shot Density)

Perforation Length (Cement to End of Perforation)

Entrance Hole Diameter in Casing  = Phase Angle © 2013 Halliburton. All Rights Reserved.

MF - 210

Casing

Ideal Perforating  No Crushed Debris

Cement

Perforating Main Challenges Clean Tunnel Reservoir Rock

 No Damaged Permeability Zone  Deeper Effective Depth of Penetration Perforation Depth

 Original Productivity Index

Challenges  Partial Blocking of Perforation Tunnel  Damaged Permeability Crushed Zone

Crushed Debris

 Reduction in Effective Depth of Penetration

Damaged Permeability Zone

 High Pressure Differential drop at Sand Surface  Reduction in Productivity Index  Post-perforation Clean-up Operation Mini-Frac, Acid,…etc. © 2013 Halliburton. All Rights Reserved.

MF - 211

Cement

 Frequent Workover jobs using Coiled-Tubing

Casing

Perforation Depth Reservoir Rock

Cement

Casing

Typical Near Wellbore Damage Profile Damaged Permeability from Production, Injection, or Drilling, kd

rd

S = Sd + Sc + Sp + Sa S = Total skin damage

Undamaged Permeability, k

Sd = Formation damage from drilling, cementing, completion fluid, clay swelling, and fines migration (changes with Sp) Sc = Partial completion skin Sp = Perforation geometry skin (perforator type & crushed zone damage) Sa = Shape factor skin

Cement

Casing

Open Perforation Tunnel Charge & Rock Debris Pulverized Zone Compacted Zone, kc

© 2013 Halliburton. All Rights Reserved.

Grain Fracturing Zone

MF - 212

Production Performance at Different Skin Values Cumulative Production Mbbl

16 S = 0.0 S=5

12

S = 10 S = 15 S = 20

8

S = 25

4

0

0

12

24

Time, Months Qp Sensitivity to Skin value! © 2013 Halliburton. All Rights Reserved.

MF - 213

36

48

Factors Influencing Perforation Efficiency “Well Productivity”  Formation Compressive Strength Sandstone Carbonates  Perforation length Porosity Compressive Compressive Strength Strength %  Gun phasing PSI PSI  No. of SPF 5 29,915 15,083 10 18,353 9,175  Perforation diameter 15 11,933 6,698  Crushed zone damage 20 6,985 4,911  Wellbore damage 25 3,182 3,074  Anisotropy 30 1,323 1,561  Dipping formation or slanted wellbore in an anisotropic reservoir © 2013 Halliburton. All Rights Reserved.

MF - 214

Porosity vs. Formation Compressive Strength Compressive Strength vs. Porosity Compressive Strength, Mpsi

30

Sandstone 20

Carbonates

10

0

0

© 2013 Halliburton. All Rights Reserved.

5

10

15

Porosity, %

MF - 215

20

25

30

Effect of Perforation Length, Phasing, and Shot Density on Productivity Ratio 1.2

SPF

16 8 90°

Productivity Ratio

1.1

4

Open Hole

1.0

Phasing

SPF 16 8 4

0.9 0.8

12-in. Wellbore Diameter 0.4-in. Perf. Diameter No Crushed Zone No Damaged Zone No Turbulence

0.7 0.6

0° Phasing

0

© 2013 Halliburton. All Rights Reserved.

3

6

9

12

Perforation Length, inches MF - 216

15

(After Tariq, 1987)

Perforating Methods

Wireline Casing Guns © 2013 Halliburton. All Rights Reserved.

Through Tubing Perforating MF - 217

Tubing Conveyed Perforating

Importance of PL/Perf in EOR Main Objectives:  Diagnose Reservoir Production Performance at Sandface PL 27-11-2002

 Diagnose Well Suitability – Optimize Well Conditions  Determine Zonal Injection/Production Contribution

15153-15210

15222-15253 Qo = 2014 POBD Pwf = 5697 psi

15260-15276

 Implement EOR Process (at Sandface) 15324-15349

 Monitor Reservoir Response

0

20

40

60

Choke= 1/2"

© 2013 Halliburton. All Rights Reserved.

MF - 218

80

Importance of PL/Perf in EOR Diagnose Well Suitability – Optimize Well Conditions Determine Zonal Injection/Production Contribution Theoretical Flow

12-10-2007 01-09-2005 PLPL12-10-2007 27-11-2002 PLPL01-09-2005 PLPL27-11-2002

Profile %

24-02-2008 PLPL 24-02-2008

15153-15210

15222-15253 Qo = 2014 POBD Pwf = 5697 psi

Qo = 1791 POBD Pwf = 5330 psi

15260-15276

Qo = 1746 POBD Pwf = 5322 psi

Qo = 1098 POBD Pwf = 4380 psi

15324-15349 0

20

40

60

Choke= 1/2"

80

0

20

40

60

80

0

20

40

60

80

0

20

40

60

80

Before

- Dramatic Improvement in P.I. from 0.35 to 0.91 bbl/psi © 2013 Halliburton. All Rights Reserved.

MF - 219

0

20

After

40

60

80

Importance of PL/Perf in EOR Inflow/Outflow Curves, Well:2008) F-A Proposal Feb., 2008 Predicted (16 Feb. Sensitivity to: Flow Restriction I.D. (Choke) Inflow/Outflow Curves for FUL-91 ENERO2008 PROPUESTA Sensitivity To: Flow restriction I.D. (Choke)

Pressure (psia) at Casing, MD 15181.500 ft Downhole Pressure – psi

10000

7500

9

5000

9

9

9

9

99

9

K = 14.5 mD Matched Skin = 25 Qo = 1100 POBD Pwf = 5050 psi

2500

0

9

99

Inflow: All values Outflow: 1-1/4" Outflow: 1" Outflow: 7/8" Outflow: 3/4" Outflow: 5/8" Outflow: 1/2" Outflow: 9 7/16" Outflow: 3/8" Outflow: 5/16" Outflow: 1/4"

0

700

1400

Total Production Rate - (STB/day) BOPD Total Production Rate

2100

2800

Case Study - Significant Reduction of Skin Damage - Increase in Pwf from 4380 to 5322 psi - 59 % Daily Production Increase (648 BOPD) - Dramatic Improvement in P.I. from 0.35 to 0.91 bbl/psi

© 2013 Halliburton. All Rights Reserved.

MF - 220

Gun Systems

© 2013 Halliburton. All Rights Reserved.

MF - 221

EOR in Heavy Oil Reservoirs

© 2013 Halliburton. All Rights Reserved.

MF - 222

223

Oil ºAPI vs. Viscosity ºAPI … is a measurement derived from Oil Density at Surface Conditions ! Density g/cm³

Conventional Oil

°API 50 45

Condensate

40 30

~11.3ºAPI

0,825 Light Oil

20 Heavy and Extra Havy Oil

0,780 0,802

0,876 0,934

Heavy Oil 10 0

Extra Heavy Oil Tar & Bitumen

ºAPI = (141.5/SG at 60 °F) - 131.5

1,000

< 100 cp 100 - 1000 cp 1,076 1000 – 10,000 cp >10,000 cp

API: American Petroleum Institute © 2013 Halliburton. All Rights Reserved.

MF - 223

Light - Intermediate Heavy Extra Heavy Bitumen

224

Viscosity of some Common Substances centipoise 0.1

FI α 1/µ

Water

1.0

Milk 10.0

Vegetable Oil

Conventional Oil Light & Intermediate

100.0

1,000.0

Motor Oil

Honey 10,000.0

Ketchup

100,000.0

1,000,000.0 Source: Oilfield Review © 2013 Halliburton. All Rights Reserved.

Mayonnaise

MF - 224

Peanut Butter

Athabasca Oil Sand

225

Oil ºAPI vs. Viscosity 10000000 Canada

Viscosity (cP) at reservoir T

1000000

US

Bitumen

Venezuela/Colombia China

100000

Extra Heavy

10000

India/Indonesia US Canada

1000 100

Light & Intermediate

Heavy

10 1 0.1

0

5

PI α 1/µ © 2013 Halliburton. All Rights Reserved.

10

15

20

25

30

35

40

45

50

API Gravity Source: OGJ EOR Survey (April 2004)

MF - 225

Where ..?

© 2013 Halliburton. All Rights Reserved.

MF - 226

227

Definition of Reservoir Characteristics

PI α K

Production Tubing

Kv

Reservoir

© 2013 Halliburton. All Rights Reserved.

MF - 227

Kh

228

Differentiation between various Reservoir Characteristics

PI α Kh/µ

ƒ

Depth & Pressure

K1 h1 µ1

h1

Arcilla

Kv

K2 h2 µ2

Kh

Maximizing Drainage area improve production, but there are considerations………!!! © 2013 Halliburton. All Rights Reserved.

MF - 228

h2

Temperature Effect on Heavy Oil Considering Productivity Index

K h µ

PI ≈ Kh / µ

: Core, Logs, Well Test : Logs, Core, Seismic : Fluid Sample, May be Logs

© 2013 Halliburton. All Rights Reserved.

MF - 230

Temperature Effect on Heavy Oil Considering Productivity Index

PI ≈ Kh / µ

K= 3000 md

PI ≈ 3000 x 20m / 100,000 ≈ 0.6

K= 6000 md

PI ≈ 6000 x 20m / 2000 ≈ 60

For Every 7ºC increase in Temperature the Viscosity drops to about half of its value

PI ≈ 3000 x 20m / 50,000 ≈ 1.2 © 2013 Halliburton. All Rights Reserved.

PI ≈ 6000 x 20m / 1000 ≈ 120 MF - 231

Heavy Oil Production EOR Methods

Production Methods Primary

 Cold Production  MLT  CHOPS

Thermal

Vapor  CSS  Flooding  HCS  SAGD

Combustion  CIS  THAI™  Top Down

Hybrid Methods © 2013 Halliburton. All Rights Reserved.

MF - 232

None Thermal

 Water Flooding  CO2, IGI  Chemical Injection  VAPEX

Sequential

Heavy Oil Production EOR Methods Nomenclature  CSS (Cyclic Steam Stimulation)  HCS (Horizontal Cyclic Steam Stimulation)  CIS (Combustion In Situ)  IGI (Inert Gas Injection)  SAGD (Steam-Assisted Gravity Drainage)  CHOPS (Cold Heavy Oil Production with Sand)  PPT (Pressure Pulsing Technology)  VAPEX (Vapor-Assisted Petroleum Extraction)  THAI™ (Toe-to-Heel Air Injection)  MLT (MultiLateral)  Hybrid Combining more than one method © 2013 Halliburton. All Rights Reserved.

MF - 233

Heavy Oil Production Technology 1985 Horizontal Wells

X

X

Vertical Wells

Cyclic Steam Stimulation

X

Thermal

None Thermal

Isaacs, 1998

In 1985, almost the only commercial technology available for Heavy Oil Production in high Porosity Sandstones CSS – Cyclic Steam Stimulation © 2013 Halliburton. All Rights Reserved.

MF - 234

Heavy Oil Production Technology 2008 Horizontal Wells

Vertical Wells

SAGD* HCS* THAI™?

Cold Flow* +PPT VAPEX? IGI*…?

Cyclic Steam Stimulation

CHOPS*, PPT

Thermal

None Thermal

* Completed Commercialization

Starting 2008, Commercial Technologies apply in all the categories © 2013 Halliburton. All Rights Reserved.

MF - 235

Heavy Oil EOR Methods

Thermal Methods Thermal techniques aim to reduce oil viscosity in order to increase its mobility, through the application of heat.  Steam Flooding  Cyclic Steam Stimulation  Horizontal Cyclic Steam Stimulation  Steam-Assisted Gravity Drainage  In-situ combustion “Fire flooding” © 2013 Halliburton. All Rights Reserved.

MF - 236

Steam Flooding

© 2013 Halliburton. All Rights Reserved.

MF - 237

Cyclic Steam Stimulation Long soak periods may be desirable in order to fully utilize the injected heat energy

© 2013 Halliburton. All Rights Reserved.

MF - 238

Steam-Assisted Gravity Drainage - SAGD     

Pair of horizontal wells are drilled into the oil reservoir, One well a few 4 - 6 meters above the other High pressure steam is continuously injected into the upper well Steam and gases rise because of their low density compared to oil below Heated oil moves downward into the lower well, where it is pumped out

© 2013 Halliburton. All Rights Reserved.

MF - 239

Steam-Assisted Gravity Drainage - SAGD  Steam is first circulated in both wells  Heated heated heavy oil flows to the lower well  The freed space becomes filled with steam forming a steam chamber

 The steam chamber expands upwards from the injection well  Oil is heated and flows down along the steam chamber boundary via gravity © 2013 Halliburton. All Rights Reserved.

MF - 240

Combustion In-Situ (Fire Flooding)  Ignition occurs inside the formation by continued injection of air  A fire front is advanced through the reservoir  Oil mobility is increased by reducing its viscosity caused by the combustion gases heat

© 2013 Halliburton. All Rights Reserved.

MF - 241

Toe-to-Heel Air Injection - THAI™

© 2013 Halliburton. All Rights Reserved.

MF - 242

Hydrocarbon Recovery Process

Non-Thermal Methods Non-thermal recovery techniques could be considered for:  moderately viscous oil “50-200 cp”,  thin formation “less than 30 ft”,  low permeability “less than 1 md”  depths greater than “3000 ft”. Non-thermal methods aim to reduce the viscosity of oil, increase the viscosity of the displacing fluid, or reduce the interfacial tension. 1. Polymer flooding 3. CO2 or Inert Gas Injection 5. Emulsion flooding © 2013 Halliburton. All Rights Reserved.

2. Surfactant flooding 4. Water flooding MF - 243

Heavy Oil Non-Thermal Recovery Methods Injecting specific fluid into the reservoir to help recover the unmovable heavy oil

     

© 2013 Halliburton. All Rights Reserved.

MF - 244

Polymer flooding Surfactant flooding CO2 Injection IGI Water flooding Emulsion flooding

Heavy Oil Non-Thermal Recovery Methods Miscible Recovery These recovery methods include both hydrocarbon and non-hydrocarbon miscible flooding. Involve the injection of gas (Co2, N, IG,…etc.) that either are or become miscible with the heavy oil under reservoir conditions. This reaction lowers the oil viscosity, making it more easy to produce, either by water drive or injected gas pressure

© 2013 Halliburton. All Rights Reserved.

MF - 245

Heavy Oil Non-Thermal Recovery Methods Chemical Recovery These recovery may include surfactant, polymer and/or alkaline flooding. After a reservoir is conditioned by water pre-flush, specific chemicals are injected to reduce interfacial tension (help release oil), and/or improve mobility (reduce channeling). This action is followed by injecting a driving fluid (water) to move the chemicals and resulting oil bank to the production well

© 2013 Halliburton. All Rights Reserved.

MF - 246

Status of the Methods of Heavy Oil Production Year

Status

Mejor Application

CHOPS

~20

$$$ commercial

Zone thickness in the range of 9’ a 60’, without Moveable Water

SAGD

~6-8

$ economic

Limited to thick zones > 45’-60’

2-3

$$ new

In combination w/ other methods (Cold Production, CHOPS)

VAPEX

?

various field Tests

For Oils > 100 cP, or with SAGD

IGI

>15

$$$

CSI/HCS

3-5

$

Method

PPT

© 2013 Halliburton. All Rights Reserved.

High Lower MF - 247

kv and Lower 

k than SAGD, > 40’

Summary Reservoir & Production Diagnosis:  RMT- Elite Reservoir Evaluation behind Casing

Spectral Flow Log Water flow movement inside/outside pipe

 PLT / CAT / Gas Holdup Production type & Rate evaluation

Completion & Borehole Diagnosis:  CAST-V Cement Evaluation & Casing Inspection

 CBL & RCBL Cement Evaluation Top of Salt

 MIT & MTT Casing and Pipe inspection © 2013 Halliburton. All Rights Reserved.

MF - 250

Summary Perforation Techniques & Methods:  Overbalanced, Balanced, Underbalanced, Extremely overbalanced, Focused energy, Hydraulic  Wireline Casing Guns, Through Tubing Perforating, Tubing Conveyed Perforating

EOR in Heavy Oil Reservoirs:  Thermal  CSS, Flooding, HCS, SAGD  CIS, THAI™

 Non-Thermal 

Polymer Water Flooding



CO2 Flooding, IGI



Chemical Injection

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Considerations Before implementing any EOR method, It is critical to understand:

 Changes in Reservoir Behavior throughout the Fields Lifecycle  Detailed Evaluation of Remaining Hydrocarbons  Updated Reservoir Fluid Contacts  Complete Production Surveillance History  Conformance and Control of Undesired Fluids  Completion and Wellbore Alterations and if Repairs are Required  Both the Injection and the Producing Wells are Subject to Proper Integrity Checks

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