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woodplc.com
Production Chemistry Networking Event 3
A Holistic Systems Approach to Production
Chemistry Input to Flow Assurance
Colin Smith – Production Chemistry Technical Authority
E-mail: [email protected]
Tel: +44 (0)1784 417154
Event date: 02/10/2018
Event hosted by Richard Barr, Proserv
What is Production Chemistry?
2 A presentation by Wood. October 2018
Impact Gas Water Liquid
Hydrocarbons
Production HydratesEmulsions, Scale,
Sand/fines
Wax, Asphaltenes,
Naphthenates,
Foaming
Product ValueH2S, CO2, DMS,
Mercaptans, Mercury
Desalination, SRP,
PWRI, Reuse,
Unconventional
BS&W, Sulphur,
Mercury, Organic
chloride
Asset IntegrityH2S, CO2, chemicals,
Corrosion
Chloride, Bacteria,
Sand, Hg, Corrosion
Organic acids,
Organochlorides
Environmental /
HSE
Compliance
Flaring / Emissions
Oil in water, WSOs,
Contaminants,
NORM/LSA Scale
Oil in water
Organic Mercury
Production Chemistry is the management of the chemical properties of fluids that can impact production, product value, asset integrity or
environmental/HSE compliance
Unmitigated Production Chemistry - 1
3 A presentation by Wood. October 2018
GAS HYDRATES
NORM SCALE
WAX- PIGGING DEBRIS
ASPHALTENE
FLOCCULATION
B
L
O
C
K
A
G
E
S
Unmitigated Production Chemistry - 2
4 A presentation by Wood. October 2018
CALCIUM NAPHTHENATE (CaN)
CORROSION
Production Chemistry Issue - Severity
5 A presentation by Wood.
PC / FA Issue Location of Fouling /
Deposition
Fouling / Deposition to Form Blockage -
Severity
Production Flow Period to See a
Problem
Hydrates Subsea Very High Hours - Days
Halite Downhole/subsea Very High Days
Naphthenates Topsides High 2 – 4 weeks
Asphaltenes Downhole Medium to High Months
Wax Downhole/Subsea Medium to High 4 weeks to 3 months
Scale Downhole /
Subsea / Topsides
Medium to High > 6 months typically (can be < 3 months)
Biofilms / Biofouling
Subsea Medium to Low > 6 months to years
Emulsions All Low Years
Sand (assumed well
completions hinder sand production rate)
Topsides Low Years
Considering worst case scenario – uncontrolled production, ~ 120 Kbopd
New Oil & Gas Field Development Projects
6 A presentation by Wood. October 2018
Typically between Appraise-Concept Select-Define phases
Project Team• Project Lead/Manager/Engineer
• Front End Engineer(s)• Process Engineer(s)
• Reservoir Engineer(s)
• Subsea Engineering Specialists
• Corrosion / Materials Engineer
• Production Technology / Petroleum Engineering (Wells)
• Flow Assurance Engineer(s)
• Process Chemist
A collaborative team approach!• No working in isolation
• Constant communication, data sharing / review
• Regular team meetings / workshops / peer reviews
• Joint reports
Project Life Cycle – FA/PC/Process Activities
7 A presentation by Wood. October 2018
Exploration
& AppraisalConcept
Select Define Execute Operate
Life of Field Operation
Decommission
Core Analysis &
Geochemistry
Longer Term
Water Injection
Studies. EOR,
Chemical Squeeze
Onsite & Lab Core
Flooding
Formation &
Injection Water
Composition
CO2, H2S, He, RSH, Hg,
Radon, Arsenic,
Vanadium, Calcium
Naphthenate
Contaminants
PC Risks: Scaling,
Asphaltene, Wax
deposition, CaN
PVT Analysis
Implications
Well Test
Sampling SoW
Chemical Injection
Design, Chemical
HSE
BOD
Start-up, Shut-
down Strategies
FEED, Flowline
Design, Field
Layout
Mitigation
Philosophies &
Strategies
Fluid & Material
Compatibilities
Hydrate, Wax,
Corrosion,
Asphaltene, Scale
Deposition
Modelling
Corrosion and
Chemical
Monitoring
Chemical
Management
Onsite Lab Design
Operating and Lab
Procedures
Commissioning
Plan
Wet Lay-up,
Hydrotesting
Chemical
Packages
Chemical Selection
& Qualification
Commissioning
Support
System
Performance
Monitoring &
Evaluation
EOR Options Well
Workover
Process &
Chemical
Optimisation
FDP, WFSs, BfD,
CSR, prelim CRR
Final CRR
Oil assays, oils
blending tests
• Hydrocarbon phases properties & composition
– Oil, gas, condensate, reservoir fluid
• Formation water properties & composition (contamination)
• Gas phase issues
– Corrosion
– Hydrates
– Souring / H2S
• Oil / Condensate phase issues
– Asphaltenes
– Wax (deposition and gelation)
– Corrosion
– Emulsions / rheology / separation / foaming
– Naphthenates & Soaps
– Scaling (incl. NORM, halite, sulphides etc.)
Prod. Chem. Input to Flow Assurance – 1
8 A presentation by Wood. October 2018
• Water phase
– Scaling
– Corrosion
– Separation / Emulsions
– Microbiology
– Produced water treatment
– Water Injection / recycle / reuse / disposal
• Contaminants – Across all phases
– Organic acids
– Sulphur species
– Heavy metals, e.g. Mercury
– Arsenic / arsenates
– Organochlorides
• Use of Analogue fields fluid data if have no samples/poor samples
• Understand your fluids – define the issues – A correct basis is a must!
Prod. Chem. Input to Flow Assurance – 2
9 A presentation by Wood. October 2018
PC & FA Workflows
10 A presentation by Wood.
FA & PC new oil & gas field developments workflows
• Oversee production fluid characterisation studies
• Collaboration = well defined fluids basis of design (BoD)
• Risk assess for wax, asphaltenes, hydrates, emulsions, foaming,
souring, corrosion, scaling, soaps, contaminants, water
treatment etc.
• Combination of modelling, lab experiment & analysis work
• Define PC/FA problem solutions – design, operational &
chemical solutions
• Oversee the screening & qualification of chemicals &
compatibility
• Compile Chemical Requirements Reports (CRRs)
• Develop mitigation strategies
incl. Chemical Management Strategy (CMS)
Asphaltene Risk Assessment Workflows
11 A presentation by Wood. October 2018
PC – FA Work Program - 1
12 A presentation by Wood. October 2018
• Develop and set the Production Fluids Basis
- Formation Water composition / properties
- Hydrocarbon oil/condensate properties
- Gas composition
- Contaminants
• Identify any BoD gaps/uncertainties requiring further work (Holds)
- Perform lab testing required to fill any basis data gaps
- Actual or restored samples requirement
- Identify best labs to do fluid properties work, e.g. oil/condensateliquid properties
• agree SoW, generate RFQs, send to labs & review responses
• select best laboratory for work & generate PO
• oversee lab testing & handle any queries,
• Review laboratory testing report
• interpret results for project
- Run simulation modelling as required, e.g. scaling predictions
PC – FA Work Program - 2
13 A presentation by Wood. October 2018
• Full Production Chemistry risks assessment developed
(including modelling & comparison to analogues, as required)
- Hydrates
- Scale (including halite for FW breakthrough case)
- Corrosion
- Emulsions / separation (soaps)
- Foaming
- Wax,
- Asphaltenes
- Naphthenates
- Contaminants (including Mercury) & meeting export specs
- Produced water treatment aspects
- Microbiology (biofouling risk)
• Full FA risks assessment performed – PC/FA data exchanged
• Rank the PC/FA risks & flag up those needing chemical control
PC – FA Work Program - 3
14 A presentation by Wood. October 2018
• Define high level chemical requirements to control any identifiedrisks
- Hydrates
- Corrosion
- Scale (+ halite?)
- Emulsions / separation & produced water treatment (PWT)
• Liaise with project disciplines – define system conditions underwhich chemicals will be applied (e.g. P, T, flow regime, shear stressetc.) including if any need for downhole injection – Liaise with FA
• Engage various chemical vendors for their recommended chemicaloptions & their product application ranges / limitations
- Product stability,
- Product performance,
- Environmental aspects
- Product compatibility characteristics
- Input into umbilical core chemical requirements
PC – FA Work Program - 4
15 A presentation by Wood. October 2018
• Oversee any laboratory qualification testing of recommendedchemicals, define target chemical injection rates, select injectionlocations & interpret test results for project
- Define SoW, RFQs to labs, select a lab, interpret results
• Investigate compatibility of tieback and hub production fluids
• Investigate compatibility of treatment chemicals
- With production fluids
- With selected materials (steels, elastomers)
- With hub production fluids
- With hub treatment chemicals
- Any common chemicals possible?
• Work with other disciplines (e.g. FA, subsea) to design the chemicalinjection facilities (downhole, subsea & topsides, plus umbilical)
• Define number of cores needed, core diameters, chemicaldeliverability etc.
PC – FA Work Program - 5
16 A presentation by Wood. October 2018
• Field production chemicals regulatory requirements preparationbefore EXECUTE phase
- HSSE,
- Environmental,
- Chemical permitting etc.
• FA Summary report generated
• Ongoing throughout – generate a Chemical Requirements Report,CRR
- A catch all ‘live’ document
• Move into FEED or done during FEED / pre-FEED
Production Chemistry & FA Integration
October 2018
• Representative fluid samplesrequired
• Sample testing providesexperimental data (wax,asphaltenes, hydrates etc.)
• FA modelling provides riskassessments for different scenarios& helps decision making on theoverall concept
• Comparison of lab test data & FAmodels output – tune and validatethe models
• Apply operational experience
• Use analogues knowledge
• Apply lessons learned
• Co-operation is key to yieldingrepresentative results
PC+FA Involvement
PC+FA Involvement
When it goes right! (subsea tieback to existing hub)• Steady state flow covered – mitigations agreed by team
• Transient operations covered (start-up/restart/shutdowns)
– E.g. hydrate management (THIs, KHIs, cocktails)
• Impact of flow regime/slugging/surges/Liquid hold up) – line/riser
• Chemical injection locations agreed by project team
• Chemical injection facilities designed with flexibility (+sparing) for life of field (plus storage requirements, cleanliness etc.)
– Allow for low to high production rates (+ turndown)
– Allow for compositional changes (e.g. inj. water breakthrough)
• CIMVs option considered collectively (team)
• Umbilical core design & chemicals deliverability optimal/flexible
• Chemical compatibility / core flushing / environmental impacts
• Operating philosophies and management strategies developed collectively by various disciplines
Proactive PC – FA Collaboration - Output
October 2018
Wax related properties derived in laboratory (dead / live fluids)
– Used for tuning FA modelling of wax deposition in subsea pipelines
– For different scenarios look at live WAT vs arrival temperatures
– Impact of pressure/gas/water on gel strength / restart pressure
– Drive wax management strategies
– Select insulation/heating/pigging/chemicals etc.
PC – FA Key Collaboration – Wax Example
October 2018
Exploration
Identify & Assess
WAT / WDT
Wax Content
Pour Point (PP)
Viscosity
Appraisal / Development
Identify & Assess / Select
Further WAT / PP tests
HTGC
Yield Stress / Restart
Wax Deposition Rate
Live WAT determination
Development
Select
Chemical Tests
Thermodynamic Modelling
Deposition Modelling
Flow Loops
R&D
Required Optional
Laboratory Testing - Wax
20 A presentation by Wood.
Gelation /
Pipeline Restart
Pour Point
Yield Stress /
Pressure
Deposition
WAT
Viscosity
HTGC
Analysis
Wax Diffusion
Coefficient
Gelation/
Pipeline Restart
Pour Point
Yield Stress/ Pressure
Deposition
WAT
Viscosity
HTGC analysis
Wax Diffusion Coefficient
Hydrate Risk Assessment – Lab Experiments
21 A presentation by Wood. October 2018
Temperature: -80 to +250 oC
Pressure: 6,000 psia (400 bar)10,000 psia (700 bar) 30,000 psia (2,000 bar)
Visual Autoclave Rocking Autoclave High Pressure Cell
Run lab experiments under different conditions and plot
experimental points on model hydrate curves
PC – FA Key Collaboration – Corrosion Example
22 A presentation by Wood. October 2018
Gas – Condensate subsea pipeline corrosion modelling– Condensation rates modelling
– Relative formation vs condensed water rates over LoF
– Key parameters in water types
• Organic acids content
• Bicarbonate / alkalinity
• pH
• Fe Saturated?
– Corrosion inhibitor screening / qualification in lab
• FA/CE/PC agree P/T, flow rate, ratios, pCO2, pH2S, acetic acid?
• FA supply fluid velocity & pipewall shear stress data – PC then decide optimal test method to screen CI chemicals (vendor / lab input)– LPR, RCE/HPRCE/HPRCA/jet impingement/Flow Loop
– Coupon / segmented weld electrode
– Corrosion rate modelling (Norsok/ECE etc.) - comparison
– Joint interpretation of data – corrosion allowance, CI rate/availability
Any Questions?
23 A presentation by Wood. October 2018