Fluid Mapping While Drilling Service

Real-time Fluid Mapping While Drilling service enhances identification

and validation of downhole fluids

Yon Blanco

December 14, 2017

Formation Sampling While Drilling (FSWD)

Representative volumes of formation fluid at down hole conditions with minimum filtrate contamination and no phase separation

0 0

Con

tam

inat

ion

Pumped Volume, liters

50 100 150

0.1

0.2

0.3

0.4

0.5

0.6 LWD 43 h after drilling WL 177 h after drilling

0 0

Con

tam

inat

ion

Pumped Volume, liters

40 80 120

0.1

0.2

0.3

0.4

0.5

0.6 LWD 5.5 h after drilling WL 174 h after drilling

20 60 100

SPE 128249

Fluid Mapping-While-Drilling Service Applications

Static Reservoir Mapping

Fluid Mapping

Reservoir Exposure

Maximization

Productivity Steering

• Map and characterize reservoir fluids

• Enhance well placement in complex well profiles

• Reduce Risk

While drilling evaluation

Trajectory optimization

Geosteering operations

Reservoir models and FDP

Target to be drilled identification (from models and seismic)

Reservoir models update/validation

Fluid Mapping-While-Drilling Service Overview

Pressures, Downhole Fluid Analysis (DFA) and physical samples

Fluid mapping while drilling made possible for the first time

Composition (C1, C2, C3, C4, C5, C6+, CO2)

GOR, asphaltene content, FVF

Contamination estimation

All answers given with estimated uncertainty

Full Reservoir evaluation in a single drilling BHA

Opening the way to real-time productivity drilling, beyond just

sampling and DFA

Proven successfully in a variety of environments and wellbore

geometries

Fluid Mapping While Drilling Applications – Added value

Rig

Spr

ead

Rat

e

Well Trajectory

Lan

d

Vertical

Off

sho

re

Horizontal

60–70%

20–30%

<10%

Appraisal / Development

Reservoir (productivity) steering

Exploration wells

Data assurance

Development wells

Bypassed zone

Brownfield evaluation

Exploration/Appraisal

• Economics – booking reserves • Fluid type

• Distribution of fluids

• Volumes

• Recovery factors

• Completion strategies

• Facilities, flow assurance

• EoS modelling

• Reservoir structure, compartmentalization

Development

• Fluid typing

• By-passed pay, changes in fluid contacts

• Movable fluids

• Fluid variability / mapping – especially horizontal wells

Fluid Mapping-While-Drilling Service Service Specifications

SCM

SCM

POM

Hydra

D U

P0 P0’

Pump

DFA #1

DFA #2

Isolation valve

Pretest

Probe

Exit port

D

U

D F A

D F A

P1

P2

Probe Module

Dedicated pretest module

High accuracy Quartz gauge (30 kpsi)

MEMS SOI secondary gauge

ECD Monitoring

Large diameter probe

H2S resistant flowline

H2S coupons

Two setting pistons – no orientation

Max differential pressure: 8,500 psi

Hole size: 8½ – 10½ in

150 degC

Fluid Mapping-While-Drilling Service Service Specifications

SCM

SCM

POM

Hydra

D U

P0 P0’

Pump

DFA #1

DFA #2

Isolation valve

Pretest

Probe

Exit port

D

U

D F A

D F A

P1

P2

Pump Out Module

Electromechanical Displacement Unit

Max differential pressure: 5,000 psi or 7,000 psi

Rate: 0.1 to 40 cc/s or 0.1 to 29 cc/s

H2S resistant material

Constant rate and differential pressure modes

Mud circulation

Downhole Fluid Analyzer

Composition (C1, C2, C3, C4, C5, C6+, CO2)

Contamination monitoring, fluid typing, color

Gas/oil ratio, fluid fractions

Asphaltene content and Formation Volume factor

Fluid resistivity, temperature

Flexible placement

Fluid Mapping-While-Drilling Service Optical Spectrometry Principle

10

( )log

( )

in

out

I

I

Optical Density

Lig

ht

so

urc

e

Op

tica

l w

ind

ow

Mu

lti-

ch

an

ne

l d

ete

cto

rs

Sa

mp

le f

low

Light source Multi-channel

detector

Optical window

Sample flow

OD = 0

100%

OD = 1

10.0%

OD = 2

1.0%

OD = 3

0.1%

SPE 166464 • Estimation of Fluid Composition from Downhole Optical Spectrometry

500 1000 1500 2000Wavelength (nm)

Optic

al d

ensi

ty

Visible Near infrared

Fluid Mapping-While-Drilling Service Service specifications

SCM

SCM

POM

Hydra

D U

P0 P0’

Pump

DFA #1

DFA #2

Isolation valve

Pretest

Probe

Exit port #1

Exit port #2

D

U

D F A

D F A

P1

P2

Sample Carrier Module

• Each carrier: 3 x Bottles; Up to 4 carriers

• 450 cc PVT Bottles or 250 cc N2 compensated

• Dursan coated

• Externally mounted in collar

Job Planning - modeling

Clean up simulations are used for:

Assess sampling feasibility

Select optimal sampling parameters

Evaluate cleanup time to reach target contamination

Parameters into the numerical simulation:

Permeability and anisotropy

Filtrate and formation fluid viscosity

Wellbore trajectory, BHA design and movement

Mud and dynamic flow properties

Mud cake building, invasion computations considering

filtration from circulation during cleanup

Time After Bit (TAB) at which the sampling is

occurring (while drilling/ while POOH)

• Fluid Fractions

• Fluid Composition

C1, C2, C3, C4, C5, C6+, CO2

Gas Oil Ratio

Fluid typing (black oil,

volatile oil, condensate, wet

gas, dry gas)

• Contamination

Monitoring & Estimation

Prediction (volume/time to

contamination level)

Fluid Mapping While Drilling - RT Viewer Real-time Decision Making

While-Drilling Analysis of Hydrocarbon Composition in Gulf of Mexico

Challenge Determine capability of new sampling method to optimize sampling and

formation pressure testing processes.

Solution Use fluid mapping-while-drilling service to

obtain reservoir-representative downhole samples in a wildcat exploration well

and provide in situ fluid properties in real time.

Results Transmitted fluid compositions for C1, C2, C3, C4, C5, C6+,

and CO2 in real time for first time while drilling.

28 pretests and 6 samples obtained for full description of reservoir fluid

Delivered lab-quality, in situ fluid property analysis, which

would save an estimated 10 weeks of lab time in future

sampling operations.

Eni determined that the quality and amount of real-time data (shown above) would enable

to accurately determine pressures, fluid composition, and fluid fraction in future wells. SPE 173152 Evaluating Formation Fluid Properties During Sampling-While-Drilling Operations

0

20

40

60

80

C1 C2 C3 C4 C5 C6+ CO2

Co

mp

on

ent

(wt%

)

0

500

1000

1500

2000

GOR

GO

R (

scf/

bb

l)

Fluid Mapping while Drilling in Middle East Confirms Movable Hydrocarbon in Carbonates

Challenge Assess the production potential of a reservoir in a tight carbonate

formation with historically high sticking risk.

Solution Use fluid mapping-while-drilling service, along with multifunction

petrophysical logging-while-drilling service, to reveal the

presence of movable fluids in the low-permeability section of the reservoir.

Results Used mobility data obtained from pretests to adjust pumpout depths.

Observed hydrocarbon breakthrough within 25-45 minutes of pumpout,

significantly earlier than previously experienced in the area.

Demonstrated good agreement between Downhole Fluid Analysis and

data obtained after laboratory measurement.

Observed three-phase fluids in captured flowline samples.

Minimized known sticking risk due to the innovative stabilizer design and

optimized mud weight.

Real time and Lab water-cut data in agreement

SPE 182785

SPE 182785 Operating Sampling While Drilling Tool in Low Permeability Carbonates and Lessons Learned on Hydrocarbon Breakthrough

SpectraSphere* fluid mapping-while-drilling service is

the industry’s first to provide high-quality formation

pressure measurements, in situ downhole fluid analysis,

and reservoir fluid sampling—all while drilling.

*SpectraSphere is a mark of Schlumberger.

Publications: SPE 128249 / SPE 159503 / SPE 166464 / SPE 173152 / SPE 176126 / SPE 1788837 / SPE 182785