Day One - Thursday 29 October, 2020

DAY 1

08:30        Virtual Event Platform Opens. Login & familiarize yourself with the platform features and introduce yourself to other participants.

08:50        Chair's Opening Remarks

Preserving Assets In A Low Production Environment
How To Cost-Effectively Preserve Curtailed Wells

Given the unprecedented fall in demand of recent months, operators across the North America have had to curtail production. The speed of that fall and its subsequent impact on revenue streams has posed a direct and urgent question: how can operators cost-effectively curtail production whilst preserving the integrity of their assets?

In this opening section of the conference, we address this question from a multitude of key angles, hearing directly from leading operators in plays across North America about how they are cost-effectively protecting their assets.

OPENING KEYNOTE PANEL: PRESERVING SHUT DOWN & DRILLED-BUT-UNCOMPLETED (DUC) WELLS

09:00    Evaluating The Effectiveness Of Curtailing & Preserving Shut Down & DUC Wells From A Chemicals & Economics Perspective

This opening keynote panel sees senior personnel at leading operators across North America evaluate the effectiveness of the curtailment process in three 10-minute case studies.

How are they preserving their assets and what has been the economic impact of doing so?

1.    Assessing The Various Corrosive Threats To A Curtailed Asset & Prioritizing Asset Integrity Spend

  • What are the threats to a curtailed asset's integrity?
  • How should you prioritize these threats from both a short-term and long-term economic perspective?
  • How to do take a decision on which assets to curtail? How economically viable is curtailment when weighed against continued production?

2.    Choosing The Right Chemicals To Preserve The Well And Implementing An Effective Treatment Program

  • What are the chemical treatments available to preserve a curtailed asset?
  • How cost-effective are these treatments when weighed against the economic productivity of the asset?
  • How often do preserved assets need to be treated? What is the cost risk analysis?

3.    Evaluating The Effectiveness Of Curtailment Over The Long Term Including When Bringing A Well Back On-Line

  • How are operators tracking the effectiveness of their preservation efforts as they bring wells back online?
  • What are the early indications on whether the curtailment has been economically successful?
  • How are recent experiences being fed back into future contingency planning?

09:35        Virtual Conference Discussion & Feedback Session

An opportunity for delegates to feedback to conference on how they have addressed the challenges raised in the opening panel. What are the results they are seeing?

The session will also serve as an opportunity to question panellists on the content of their presentations.

DEEP DIVE CASE STUDY: BIOCIDE APPLICATION IN SHUT DOWN WELLS

10:00    How To Effectively Treat Water In Shut Down Wells To Prevent Bacteria Growth From Corroding Assets

With some wells being shut down for months on end, conditions downhole quickly become conducive for bacteria to grow and corrode assets, threatening the future economic viability of the well. What are the optimal biocide chemistries and applications to preserve the well?

  • What are the biocide chemistries that will prevent the well corroding in such conditions?
  • How can these biocides be applied in a cost-effective manner which preserves the integrity of the asset without damaging the economic viability of the well?
  • How does the length of curtailment impact the effectiveness of the biocides being applied?
  • What are the risks associated with delivering fewer treatments? Can this ever be a risk worth taking?
  • How can you monitor the effectiveness of the treatment once you bring the well back online?

10:25       Virtual Question & Answer Session

In an environment of curtailed production, the weight of responsibility on producing assets to deliver returns becomes greater than ever. But with downward pressure on asset integrity budgets, operators are having to weigh the integrity risks against the chemical costs those integrity risks bring with them. How can operators innovate and strike a balance between protecting those assets still producing as well as reducing their chemical spend?

PANEL: BEST PRACTICES ON OPTIMIZING PRODUCING ASSETS

10:35    How Do I Sustain My Operations With The Assets That I Have & The Budget That I have?

The risks are clear: cut back on chemical expenditure and you could meet costly failures down the line. But with budgetary pressures a practical reality, the need for pragmatic, calculated assessments as to where to prioritize chemical spend is equally clear.

In the following three 10-minute case studies, we hear from leading operators as to how they are tackling this dilemma. How are they reaching decisions and what are the economic assessments underlying these decisions?

  • What risk assessments are operators making as to the specific threats posed to their assets?
  • What chemicals & technologies are they investing in and why?
  • Which chemical treatments are they cutting back on?
  • What do they see as the cost-benefit analysis of such an approach and how does this feed into a long term economic assessment?
Matt Vivian, Production Engineering Manager,Ramrock Resources
.
Jacob Moehrig, Production Engineer,EP Energy

11:10        Virtual Conference Discussion & Feedback Session

As with the opening panel, this conference discussion and feedback session will allow delegates to relay  to conference on how they have addressed the challenges raised in the panel.

The session will also serve as an opportunity to question panellists on the content of their presentations.

11:30        Break

Corrosive Gas Mitigation
Preventing H2S & CO2 Corrosion Shutting Down Wells

Unplanned failures caused by the corrosiveness of H2S & CO2 cripple production. How can these gases and the rate of the corrosion be predicted & controlled to prevent such failures?

CO2 CORROSION PREDICTION MODELS

12:00    How To Effectively Monitor & Prevent CO2 Induced Corrosion On Tubing & Equipment Downhole

The threat to tubing and equipment from CO2 are compounded by high temperatures, pressures and stresses downhole. What are the latest tools to allow operators to accurately model C02 corrosion and prevent unplanned failures?

  • What are the tools available to accurately predict CO2 corrosion rates?
  • How can more accurate modelling allow operators to anticipate corrosion-related failures and prevent them?
  • What information and data should operators be extracting from their wells in order to improve the accuracy of corrosion models?
  • How effectively have CO2 prediction models pointed to workable solutions?
  • How effective have the solutions proved?

Moshen H Achour, Supervisor, Corrosion, Inspection & Materials, ConocoPhillips

12:25       Virtual Question & Answer Session

H2S SCAVENGER CHEMICAL INJECTION

12:35    Optimize The Efficiency Of Your H2S Scavenger Injection Program To Maximize The Economics Of The Well

Injection of H2S scavengers and corrosion inhibitors can be costly if not optimized so to use only the amount of chemical required. How can you reduce your chemical costs by only using the right amount of chemical?

  • How have operators reduced their chemical spend on H2S scavengers and corrosion inhibitors whilst reducing corrosion rates?
  • Which H2S scavenger treatments have proved effective?
  • What are the analytic tools available to monitor both gas and chemical levels and how have these been applied to tackling H2S?
  • What are the mechanical solutions that allow operators to reduce their  HS2 scavengers use?
Joe AlapatiFlow Assurance & Production Chemistry Advisor, Devon Energy
.

13:00       Virtual Question & Answer Session

13:10        Lunch

Advanced Biocide Application In Producing Wells
Biocide Application In Lateral Wells & Wells Following Frac Hits

Bacteria downhole is one of the leading causes of corrosion-related failures in wells today, and it poses particular challenges for lateral wells and wells following frac hits. What are the new chemistries and delivery methods available for biocide application in these scenarios?

BIOCIDE APPLICATION FOLLOWING FRAC HITS

14:30    Evaluate The New Biocide Chemistries & Discover How To Apply Them To Tackle Corrosion Downhole

Given the operational cost of corrosion-related failures, it is more important than ever to scrutinise the effectiveness of corrosion inhibitors. What are the new chemistries on offer to tackle this threat?

  • Why does the fracking process bring about challenges for treating bacteria and delivering biocides?
  • What are the biocides on offer to treat bacteria following frac hits?
  • How can you effectively treat bacteria when dealing with large volumes of fluids following drill outs?
  • What is the effectiveness of treatment on equipment downhole?
  • What results are operators seeing in maximising & extending the runtime of their wells?

14:55        Virtual Question & Answer Session

BIOCIDE APPLICATION FOR LATERAL WELLS

15:05    Learn The Effective Biocide Delivery Methods & Slow Release Chemistries To Tackle Bacteria-Induced Corrosion On Lateral Wells

With well tubing not extending into the lateral on wells, the vulnerability of those same wells to bacteria-induced corrosion is high. What are the optimal biocide delivery methods that will allow you to confront this threat?

  • What are the biocide delivery methods on offer for lateral wells and how effective are they at inhibiting corrosion?
  • What are the most effective ways to inhibit bacteria following fracs?
  • What slow release chemistries are available to inhibit corrosion in horizontal wells?
  • How are operators designing around the bacteria with mechanical processes to offset issues before they occur?

15:00       Virtual Question & Answer Session

15:10        Afternoon Refreshments

Mechanical & Metallurgical Solutions To Corrosion
Evaluating The Efficacy Of Artificial Lift & Metallurgy Technologies In Tackling Corrosion

Cost-effectively reducing corrosion requires mechanical & material solutions in addition to efficient chemical injection. In this next section, we look at the non-chemical solutions available and assess their effectiveness.

ARTIFICIAL LIFT & CORROSION MITIGATION

15:40    Assess How Different Artificial Lift Technologies Stand Up Against The Threat Of Corrosion - A Deep Dive Assessment Of Rod Pumping, ESP, Jet Pump & Gas Lift

Operators must consider a range of reliability factors when selecting an artificial lift mechanism. But how do the various methods fare when viewed through the prism of corrosion mitigation?

  • What are the corrosion-related failures associated with each method?
  • How can vulnerabilities in each be mitigated in a cost-effective manner?
  • How does the corrosion mitigation required for each system factor into the overall economic assessment of which lift technology to employ?
  • What results have operators seen when switching from one type of artificial lift mechanism to another?

Moshen H Achour, Supervisor, Corrosion, Inspection & Materials, ConocoPhillips

16:05       Virtual Question & Answer Session

METALLURGY FOR CORROSION CONTROL

16:15    How To Reduce Your Maintenance & Repair Expenditure Through The Use Of Corrosion Resistant Metallurgy In Well Tubulars

The reoccurring cost of chemical treatments to mitigate corrosion can profoundly impact the economics of a well. How effective has the selection of different metals for well tubulars been in reducing the amount of chemical spend required to offset corrosion?

  • What are the different metallurgies been implemented and how effective are they at mitigating corrosion?
  • How are these metals being applied to the design of well tubulars and what are the costs associated with implicating such changes?
  • What are the economics of such changes over the long-term?
  • How can different metallurgy practices be applied to tools and equipment other than well tubulars?
  • How does the change in metallurgy affect the chemical treatment required?

16:40       Virtual Question & Answer Session

The Economics Of Curtailment
Evaluating Which Assets To Keep Producing & Which To Curtail In A Down Market

Deciding on which assets to keep producing, and on how much these producing assets should produce, rests on a range of operational and economic assessments. In this end of day one  panel, we assess how leading operators have approached these decisions and what they believe the long term economic impact of those decisions will be.

END OF DAY ONE PANEL: HOW MUCH PRODUCTION TO CURTAIL IN A LOW PRODUCTION ENVIRONMENT

16:50    Evaluate How Best To Approach Questions Of Curtailing Production From A Long-Term Economic & Operational Standpoint

How have leading operators arrived at how much production to curtail and how much to continue? Do they expect a market rebound soon, and how are they preparing?

  • What is the chemical cost associated with lessening the production of a flowing well when weighed against the chemical cost of a shut down?
  • What are risks for the long-term productivity of a well that been shut down once it is brought back online?
  • When is it right to continue drilling but not completing wells? What is the economic risk assessment behind such decisions?
  • Should you curtail your low-production wells or high-production wells? Why?
Probjot SinghFlow Assurance SupervisorConocoPhillips
.
Lucas Green, Operations Technology Director,Maverick Natural Resources
.

17:15       Virtual Question & Answer Session

17:25        Chair's Closing Remarks

17:30        End of Day One

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