A guide to better oil and gas shale production
It’s essential to be able to measure the amount of gas, oil and water that is produce on any wellbore project and this can only be achieved through innovative technology. This inexpensive technology provides confirmation that a wellbore is open to flow, identifies and quantifies stage flow contribution of each phase, and provides measurement of drainage area connectivity — simply by adding small amounts of unique chemical tracers to each stage’s stimulation fluid.
To see any type of correlation between zonal productivity and the wellbore area, independent stage production can be made useful. Using this knowledge, future well development plans can be adjusted with confidence to ensure that any changes made will result in enhanced ultimate hydrocarbon recovery.
To ensure the area that is being drilled for the well is viable, improved surveillance technology has been introduced. These include seismic, micro-seismic, core, and multiple specialist log data sets. Historically, it has been difficult to place faith in surveillance data to vary future drilling or stimulation activities. At best, there was no confirmation that recovery would improve if the data was used to change the program design. Or worse still, one data set was inconsistent with another, leaving the operator unsure which to believe. Tracerco technology offers a method to prove the accuracy of these measurements, providing operators with confidence when planning future well and field development.
Using gamma ray (GR) technologies throughout a wellbore project, the colour red will signify that the drill is below the targeted area and the blue will signal that the drill is hitting the middle section. These GR observations support geological expectations.
Producing cumulative gas will be inevitable when wellbore drilling begins and will be shown when the colour changes to red — when water is present, the colour will turn blue. When organisations drill outside of zone low (toe stages), it commonly results in reduced gas production and increased water production. Drilling out of zone high (middle stages) was not detrimental. These types of stages show effective hydrocarbon production without suffering from increased water. Armed with this knowledge and by incorporating real time GR monitoring during drilling, operators can become better positioned to efficiently complete future wells in the field and remain in the more productive rock.
If you start a wellbore project above a parent well, hydrocarbon will be produced. Also note the increased production from stages in the centre section of the horizontals that was believed to result from accessing rock, not previously produced by the parent well.
The introduction of the frac tracer by Tracerco has helped industry leaders view different segments of their projects. Using this knowledge, the operator can evaluate drilling, stimulation and production decisions, and extract the full benefit of pre-completion seismic and geophysical diagnostics (seismic, log, micro seismic, landing zone, etc.) to ensure enhanced ultimate hydrocarbon recovery.
To find out more, Tracerco, specialists in waterflood and injection gas flow monitoring, has created a more in-depth article including gamma ray images.
5 Mins With ... Travis Parigi, CEO of LiquidFrameworks
ServiceMax, a leader in asset-centric field service management, has bought LiquidFrameworks, the mobile field operations management solutions company, specialising in the energy industry, from Luminate Capital Partners, a private equity firm. The acquisition enables ServiceMax to expand its field service management solutions to meet the unique challenges of the energy sector. Travis Parigi, CEO of LiquidFrameworks, reflects on the mutual benefits from the deal and how oilfield service providers can transform their legacy field operations management processes to digital systems
Briefly outline how the LiquidFrameworks acquisition benefits both companies?
Both companies are focused on providing solutions to a common business problem, field service management for enterprise organisations, using a common technology platform, Salesforce. There are rich opportunities across both companies to leverage people, knowledge and many years of domain and technical expertise that will undoubtedly benefit the combined product suite.
LiquidFrameworks will continue to support its customers through this combination with ServiceMax, further extending its competitive differentiation across the field service management landscape. On the other hand, this acquisition will better position ServiceMax to meet the demand for digital service execution in this industry while expanding its product portfolio and go-to-market channels.
How can oilfield service providers transform their legacy field operations management processes to digital systems?
Moving from legacy, paper-based systems often siloed in various departments to a digital process can be done in phases across one or more product lines on a location-by-location basis. We find that companies achieve the best results by leveraging the FieldFX product suite as the platform to deliver the most domain-specific functionality to their user base as quickly as possible yielding high ROI through increased cash flow, revenue recapture, invoice accuracy and labor reduction.
Companies often start by modeling the complexities and mechanics of their global price books and customer-specific price books using the FieldFX CPQ engine. As the foundation for all transactions the Price Books are used throughout the logical next steps of rolling out digital processes for Quoting, Scheduling, Ticketing, Timecards and Invoicing. Asset Management plays an important role as a common thread found throughout all of the modules and processes.
Field Technicians are responsible for delivering service to the customer along with operating new digital systems - anything more specific, which systems or new technologies (eg AI/ML) should they be targeting?
In the oil and gas industry the field technician or field engineer is responsible for leading the crew that delivers the service such as an open hole wireline job or a casing job or a pressure pumping service performed on location for the customer at the well site in the case of the upstream oil and gas industry.
In the case of the downstream industry, the service might be a hydro-blasting job to clean a heat exchanger at a refinery.
In either case, the field engineer must safely and effectively complete the complex and often times dangerous service for the customer during which time they must also complete various business process to track the work being executed in order that the back office can accurately invoice for the service. The FieldFX Mobile product from LiquidFrameworks enables the field engineer to track the required information for both operational data and financial data in a manner that is fast, effective and easy.
Does the post-COVID landscape provide a new start for digital field service management? What should be companies' immediate priorities?
With the recent layoffs and the workforce getting younger, the oil and gas industry is at the cusp of transformation. The oil and gas industry has been slowly digitising for many years now, but with the pandemic, this push has accelerated a pivot and implemented new ways of working.
When it comes implementing digital field service management, companies need to have a vision of totality across the organisation but be nimble and agile about taking bite-size chunks to effect change – take the highest return on investment items and divide them up and down into the service line and geography level – for the highest probability of success.