MEASUREMENT AND MONITORING OF SOLVENT PROCESSES FOR

MEASUREMENT AND MONITORING OF SOLVENT PROCESSES FOR ALBERTA’S OILSANDS: WORKSHOP 3

SOLVENT LEADERSHIP SERIES March 7, 2018

CLEAN ENERGY:

1

ADVANCED HYDROCARBONSBRYAN HELFENBAUMEXECUTIVE DIRECTOR, ADVANCED HYDROCARBONS

MARCH 7 2018

CANDICE PATONDIRECTOR, RECOVERY TECHNOLOGIES

ALBERTA INNOVATES AT-A-GLANCE

2

Role: Support economic diversification and job creation

Canada’s largest provincial research and innovation agency: the catalyst in an environment where invention, innovation and industry thrive.

3

DIGITAL

OMICS

ADVANCEDMANUFACTURINGAND MATERIALS

PLATFORM TECHNOLOGIES

SUBSIDIARIES

NEW STRATEGIC DIRECTION – FOCUSED, USER-CENTRIC CLUSTERS

Laura Kilcrease, CEO

CLEAN ENERGY

• AI Clean Energy develops and invests in strategic programs to achieve Alberta’s goals for energy, the environment and economic prosperity.

• We provide insight to the GOA on climate leadership, energy diversification and water policies, and support Emissions Reduction Alberta in technical due diligence and project management.

• Clean Energy’s strength is creating the partnerships necessary to achieve the goals.

4

Energy andGHG Mitigation

Environment and Climate Adaptation

Emerging Technologies

25%Revenue increase in cleantech

$40 billion AB’s manufacturing output

$20 billion AB’s digital economy

INNOVATION FOR IMPACTS: 2030 TARGETS – Moving Forward

CLEAN ENERGY

ADVANCED HYDROCARBONS PORTFOLIO - PROGRAMS

Advanced Hydrocarbons

Recovery Technologies

Partial Upgrading

Methane Emissions Reduction & Value Add

Bitumen Beyond Combustion

Objective: Improve the competitiveness of Alberta’s oil and gas industry; increase the value of natural resources; transition to a low carbon economy

8

MEASURING IMPACTS

9

RECOVERY TECHNOLOGIES: OUTLOOK

• Program Strategy• Improve hydrocarbon recovery efficiency by decreasing GHG

emissions, fresh water use, and supply cost

Example: Solvent-assisted recovery for deep cuts in production cost and GHG emissions

10

R & D Piloting Demonstration Commercial

ESEIEH

eMVAPEXCyclic Solvent

Process

HBEP

SA-SAGD

AACI

ES-SAGD

Solvent Driven Process

25% - 90% reduction of GHG emissions intensity

RECOVERY TECHNOLOGIES: PROGRAM DEVELOPMENT

http://www.google.ca/url?sa=i&rct=j&q=&esrc=s&source=images&cd=&cad=rja&uact=8&ved=0ahUKEwiVvLLLl_7PAhXB24MKHWH1Ad0QjRwIBw&url=http://www.edmontonsun.com/2016/04/23/university-of-alberta-pushing-fight-against-antibiotic-resistent-bugs&psig=AFQjCNFzcSLy4rrTMhKVWCqtcuep0-R2XQ&ust=1477767639223424

SOLVENT LEADERSHIP SERIES

• Workshop 1: In Situ• Workshop 2: Mining• Workshop 3: Measurement and Monitoring

11

9:15 Alex Filstein – Cenovus EnergyMeasurement and sampling plans for solvent pilots: how to generate the data we need from pilot operations.

10:15 Kyle Thacker – MEG EnergyField challenges and successes with collecting high quality samples from solvent pilots.

11:30 Haibo Huang - Director, AACI Research ProgramKey aspects of fluid sampling and analysis in solvent processes – measurement perspectives from the lab.

AACI Technical Workshop – April 19 & 20, 2017 CONFIDENTIAL

AI Clean Energy Solvent Leadership Series: Workshop 3 March 7, 2018 Calgary

Key Aspects of Fluid Sampling & Analysis in

Solvent Processes – Measurement Perspectives

from the Lab

1

Authors Haibo Huang


AI Clean Energy Solvent Leadership Series: Workshop 3 March 7, 2018 Calgary 2

Outline

Importance of solvent quantification in pilot test of solvent processes

Field fluid sample characteristics

Measurement of solvent content in field samples

Pre-analysis sample treatment

Sampling/monitoring locations

Sampling operation

New development in the subject area



Importance of Solvent Quantification in Pilot Test of Solvent Process

Main drives to mobilize oil in solvent processes

Solvent only processes at reservoir temperature – solvent dilution of oil

Heated solvent processes (no steam) – thermally assisted solvent dilution

Steam-solvent co-injection processes – solvent dilution of heated oil (thermal dominant) or thermally assisted solvent dilution (solvent dominant)

Solvent

(Vapex/CSI)

Steam

(SAGD/CSS)

Solvent + heat/steam Steam + solvent

Reduced energy intensity



Information from solvent content & composition change in produced fluid in a solvent process

Solvent injected = Solvent produced + Solvent remain in reservoir

Determine the net oil rate

Incremental oil production rate/solvent production rate - indicator of solvent impact to oil production behaviour

Determine solvent retention

Cum solvent retention/cum incremental oil production - indicator of solvent utilization efficiency

Composition change → reconditioning recovered solvent of multiple components

Accurate quantification of solvent production during the operation is important to assess the process performance



Field Fluid Sample Characteristics

Process Solvent Prod. Fluids Fluid Characteristics

Cyclic Solvent Injection C3/C1, C3/CO2, C2, CO2

Vapor, liquid • Vapor – light HCs • Liquid – oil/solvent/water

with low water content

Vapex (reservoir temp.) C4, C3 Vapor, liquid • Vapor – light HCs • Liquid – oil/solvent/water


Heated Solvent (hot Vapex) C4, C3 Vapor, liquid • Vapor – light HCs • Liquid – oil/solvent/water


Steam-Solvent Co-injection C3, C4, C6, diluent, naphtha

Vapor, liquid • Vapor – light HCs & steam • Liquid – oil/solvent/water

with high water content



Meas. of Solvent Content in Field Samples

Density measurement on the liquid samples

Applicable for samples with single component solvent rO+S+H2O (T,P) = wt%H2O x rH2O (T,P) + (100 – wt%H2O) x rO+S (T,P)

rO+S (T,P) = (rO+S+H2O (T,P) - wt%H2O x rH2O (T,P))/(100 - wt%H2O)

rO+S (T,P) = (100 – wt%S) x rO (T,P) + wt%S x rS (T,P)

* At the same T/P condition under which there is no presence of vapor phase



Composition analysis of the fluid samples using gas chromatography (GC)

Applicable for vapor phase and oil phase samples with multi-component solvent

single component solvent

Solvent content in the vapor & liquid phases from a test separator – an example of GC analysis

Vapor Phase Composition

C1

CO2

C2

C3

I-C4

N-C

4I-C

5

N-C

5C6s

C7s

C8s

C9s

C10

s

C12

s

Co

nt.

(m

ole

%)

Low C # Components in Testing Fluids_GC Analysis

Retention

Inte

nsit

y

Standards

Original oil

Oil + solvent

n-C5

n-C6

n-C8n-C7



C # distribution determined by C30+

0

10

20

30

40

50

60

C1

C3

n-C

4 n

-C5

Mcy

clo-

C5

Cyc

lo-C

6 M

cycl

o-C

6 C

8

m&

p-Xyl

ene

C9

C11

C

13

C15

C

17

C19

C

21

C23

C

25

C27

C

29

mo

le%

OSN

MR bitumen

Multi component solvent Bitumen

Solvent characteristics in the bitumen/solvent mixture Solvent content in fluid – 10 wt%

Reasonably well resolved from bitumen (insignificant overlap in composition) by GC analysis

0

2

4

6

8

10

12

14

Cyc

lo-C

6

C7

Mcy

clo-

C6

Tol

uen

e C

8 C

2-Ben

zene

m

&p-

Xyl

ene

o-X

ylen

e

C9

C10

C

11

C12

C

13

C14

mo

le%

OSN

MR bitumenBitumen

Solvent



Determine solvent content/composition change in produced fluid by GC

Established for composition analysis of crude oil

Currently used in solvent injection & steam/solvent co-injection pilots

Experienced problems

QC in sampling, pre-analysis sample treatment, analysis is critical



Pre-analysis Sample Treatment

Field gas sample (vapor streams, casing gas)

(gases: C1-4, CO, CO2, N2, NOx, H2S, SOx)

Field gas sample

(ambient T/pressurized)

Gas sample

(ambient T/P)

Meas. gas volume

Flash at 60 oC

Dry gas sample

(ambient T/P)

De-moisture

Gas sample Composition

GC

Applicable samples:

Test separator vapor phase, wellhead vapor phase


AI Clean Energy Solvent Leadership Series: Workshop 3 March 7, 2018 Calgary

Two-phase liquid sample – water/oil emulsion (Single solvent-, diluent/naphtha-diluted bitumen, water)

Field emulsion sample


De-gassed emulsion sample

(ambient T/P), meas. weight

Flash at 60 oC

Separated oil

W/O separation

Dry oil sample

GC

Applicable samples:

Test separator liquid phase

Separated water

Hydrocarbon comp.

Gas sample Gas sample Composition

GC

CS2 extraction

CS2 extract GC

De-moisture Solvent Composition



Single phase liquid sample – water (Water, organic compounds)

Field water sample


Water sample

(ambient T/P), meas. weight

Flash at 60 oC

CS2 extract

CS2 extraction

Organics Composition

GC

Applicable samples:

Secondary separator liquid phase

Residual water

Gas sample Gas sample Composition

GC



Liquid sample flash system schematic



Sampling/Monitoring Locations

Primary test separator

Vapor phase

Condenser

Condensed liquid (water + HCs)

Gases (low C# HCs +)

Liq. phase O/W

emulsion

Wellhead Vapor/water/oil multiphase fluid

Wellhead fluids High P/T

Slugged flow

Concurrent V/L/L multiple phases sample

Fluids from the separator Reduced P/T

L/L two phases sample (stable emulsion)

Multiple-stream sample (gas, condensed liquid, emulsion)



Wellhead fluids

Wellhead T/P

Flu

ids

sam

ple

Vapor phase

Homo. liquid phase

Water cut

Pre-analysis treated

Separator

Composition analysis

Ambient T/P




Separator fluids

Separator Condensed liquid sample


Separator Vapor

Sep

arat

or

liqu

id s

amp

le

Ab

ove

am

bie

nt

T/P

Vapor phase

Homo. liquid phase


Water cut

Ambient T/P



Gases




Wellhead Fluids Separator Fluids

Sampling Difficult Less difficult

Concurrent V&L phases Yes No

V-L phase separation before

composition analysis

Yes Yes

Homo. liquid phase before

composition analysis

Yes Yes

Analysis turnaround Slow Slow



Sampling Operation One-stage sample collection Appropriate sampler

Adequate volume

Operates under pressure and leak-tight

Easy to discharge the content & clean

Simple & safe to operate

Easy to transport

Adequate sample collection Sampling frequency – weekly, bi-weekly, or more

frequent in early stage and tapers off in late stage

Duplicate sample per sampling for backup need

Periodical sampling from the neighboring well(s)

Transport & storage Sampler in protection case

Stored in place with proper temperature

Accumulator sampler - suitable

Bomb or bottle sampler – not suitable



New Development in the Subject Area Two-stage sample collection Primary sampler

Connected to the sampling point on the production line

Automate multiple sampling at desired incremental volume & frequency from the production line during a sampling period

Homogenize the compound fluid sample for sub-sampling to the secondary sampler

Empty the sampler after sub-sampling (to the production line) for next sampling period

Secondary sampler Operate similarly to the one-stage sampling procedure

Secondary sampler

Wellhead T/P

Pri

mar

y sa

mp

ler

Test separator

Secondary sampler



New solvent detection methods – ITA internal study

Head-space GC for composition analysis of HC samples with water in presence A pre-GC device to separate water and other low boiling point HC compounds

from the original liquid fluid sample

Elution of the HC components through the GC column

Homogeneity of the fluid sample is important

Could eliminate the step of water-oil separation in pre-analysis treatment

NIR detection for composition analysis of HC samples NIR measurement of solvent/bitumen mixture spectra

Derive solvent component concentration profile from NIR spectra data

Quantification of multi components solvent in solvent/bitumen binary fluid system - proven

Quantification of multi components solvent in solvent/bitumen/water ternary fluid system – in progress

Detection probe operates at elevated temperature under pressure



Examples of NIR spectra: C-H stretching bands of nC4, nC5 and nC6 (left), combination bands of nC4, nC5 and nC6 (right)

Blue – nC4 Red – nC5 Yellow – nC6

NC7 concentration in bitumen/C7 mixture from NIR measurement



Inline solvent monitoring technique Sensitive to the change in oil composition

Directly probe the liquid phase without O/W separation

Robust to the process operation condition

Easy to operate & low maintenance

Cost effective

NIR implementation potential Measure solvent content in solvent/bitumen/water mixture (emulsion)

in lab needs high efficiency homogenizer to pre-treat the collected fluid sample

As the inline measurement probe enabling continuous measurement needs further development



Acknowledgments

InnoTech Alberta (ITA) – support to the R&D work

Colleagues at ITA – technical support

Colleagues from O&G companies – share knowledge & experiences on the relevant subjects

AI Clean Energy – opportunity to share the ideas/learning with Workshop participants

March 2018

Field Challenges and Successes collecting samples from solvent pilotsKyle ThackerReservoir Engineer

Overview

• eMVAPEX Conceptual Model

• eMVAPEX Benefits

• Recovery Process Evaluation – Importance of Sampling

• Solvent Recovery from Sampling

– Gas Phase

– Liquid Phase

• Sample Analysis

• Summary

2

MEG Energy Corp.Who we are

3

A Canadian oil sands company focused on sustainable in situ development and production in the southern Athabasca oil sands region of Alberta

eMVAPEX Modelenhanced Modified VAPour EXtraction (eMVAPEX)

4

Inject condensable gas (CG) to:• Maintain reservoir pressure, reducing

steam injection to near zero• Dilute the warm bitumen to further

improve viscosity• Partly de-asphalt the bitumen improving

API gravity and value of product

1 2 3Warmed bitumen mixed with light hydrocarbon is pushed toward infill well by pressure difference and gravity.

Freed-up steam is re-diverted to new SAGD well pairs to increase production.

Potential eMVAPEX BenefitsFurther reduction of SOR over SAGD/eMSAGP

Lower capital requirements to grow

Lower operating costs

Lower carbon emission intensity

Lower steam requirement per barrel reduces steam and water handling capacity necessary at the central plant facility to support future growth

Reduced energy costsper barrel

Growth results in fixed cost amortization across larger number of barrels, contributing to increased cash margin per barrel

Significantly lower steam requirement per barrel directly translate into lower GHG intensity per barrel

5

Recovery Process Evaluation

• Key Data for SAGD– Bitumen Production– Bitumen Recovery– Steam Injection

• Additional Data required for Steam/Solvent processes– Solvent Injection– Solvent Recovery

• Gas and Liquid– Bitumen/Solvent Solubility– Bitumen Quality

Requires Additional Sampling/Monitoring

6

Solvent Recovery – Gas PhaseTest Separator Overhead Gas Sample

Sample Cylinder (vacuum)

Rough Procedure1. Sample cylinder is attached2. Sample cylinder is filled

Test Separator

Challenge:Air Contamination

up to ~1%

Emulsion

Produced Gas

Oil/Water Production Header

7

Solvent Recovery – Gas Phase

• One problem with well level sampling is it does not monitor solvent recovery from the wells that are not sampled

• Gas phase solvent recovery from all producing wells can be estimated at the CPF using the:– Produced Gas Rate– Produced Gas solvent composition

Utilizing Central Processing Facility (CPF) Produced Gas Samples

Potential Sample Contamination

Solvent Recovery – Liquid PhaseTest Separator Bottoms Liquid Sample – Original Set-up for eMVAPEX Pilot


Test Separator

• Contamination by different well

Emulsion

Produced Gas

Oil/Water

Production Header

Potential Air Contamination

Potential Challenges:

• Air Contamination• Live oil flashes as the valve is

opened to the vacuum cylinder –Potentially extra gas flashing into the cylinder (Inflated GOR)

Rough Procedure1. Sample cylinder is attached2. Sample cylinder is filled

9

Solvent Recovery – Liquid PhaseTest Separator Bottoms Liquid Sample – Updated Set-up for eMVAPEX Pilot


Test Separator

• Contamination by different well

Emulsion

Produced Gas

Oil/WaterProduction Header

The Purge eliminates previous Challenges:

• Air Contamination• Live oil flashes as the valve is

opened to the vacuum cylinder –Potentially extra gas flashing into the cylinder (Inflated GOR)

Rough Procedure1. Sample cylinder is attached2. Sample cylinder is filled & Purged

10

Bitumen/Solvent Sampling

• Sample Draw Point?– Top/Bottom/Side of pipe– Sample Quill in middle of pipe – plugging issues?

• How are the samples analyzed in the lab?

• How does the presence of a solvent affect BS&W determination?

• Others?

Other Sampling Challenges

11

Bitumen/Solvent Sample Analysis

• A key component of the lab analysis is to determine solvent (C3) dissolution in the oil phase

• Lab results are compared to a vapor liquid equilibrium (VLE) estimate

Solvent Dissolution in Bitumen

12

Bitumen/Solvent Sampling

• In Steam based processes emulsion is produced to surface, but must understood in terms of Water and Oil. This is typically done with inline analyzers or sample analysis.

• How does the presence of solvent in the produced emulsion affect BS&W measurement?

• Inline analyzers may not be able to accurately measure Water vs Oil with a solvent present.

• Non-pressurized samples likely won’t capture all of the light ends

• Pressurized samples can be taken, but how will they be analyzed to capture all the light ends?

13

Emulsion Sampling and BS&W Determination

Summary

• Gas & Liquid Sampling and Lab Analysis are very important for evaluating Steam/Solvent processes

• Sampling Challenges and Successes

– Success – Using CPF Produced Gas to Estimate Total Solvent Recovery in the Gas Phase

– Success – Inline liquid sampling systems are believed to be optimal with a favorable pressure profile and the ability to purge

– Challenge – What is the ideal liquid sample draw point?

– Challenge – How are the liquid samples analyzed?

– Challenge – How do solvents affect BS&W determination?

14

Contact Info

Kyle Thacker, P. Eng.Reservoir Engineer, Reservoir & [email protected]

15

mailto:[email protected]

SDP/Hot Solvent Projectmeasurement

Alex Filstein, P.EngCenovus Energy IncReservoir Engineer | Technology DevelopmentDirect: (403) 766-3266 | Cell: (403) 604-1296

Natasha Pounder, P.EngCenovus Energy IncProcess Engineer | Technology DevelopmentDirect: (403) 766-3112 | Cell: (204) 583-6915

Documents

MEASUREMENT AND MONITORING OF SOLVENT PROCESSES FOR