Category: Oil & Gas

01 Apr 2020

OptaSense Authors Pen New Oilfield DAS Application Article

"Making Sense of Unconventionals With DAS" Appears in Oilfield Technology Magazine

Members of the OptaSense Oilfield Services technical team recently penned an article for Oilfield Technology magazine. The article, “Making Sense of Unconventionals With DAS,” written by Dr. Marcel Grubert, Dr. Xinyang Li and Dr. J. Andres Chavarria, provided a review of applications of distributed fiber optic acoustic and temperature sensing in unconventional reservoirs. 

12 Feb 2020

OptaSense Sponsors First EAGE Workshop on Fiber Optic Sensing

 

OptaSense will be the Lanyard Sponsor for the First European Association of Geoscientists & Engineers (EAGE) Workshop on Fiber-Optic Sensing for Reservoir and Production Monitoring, March 9-11, 2020, in Amsterdam, The Netherlands.

The aim of this workshop is to solidify the understanding of fiber-optic sensing technologies within the geoscience community while highlighting successful applications and findings. 

Rapidly advancing developments in fiber-optic sensing technologies, such as those offered by OptaSense Oilfield Services, have led to increased use in reservoir and production monitoring applications within the energy industry. Distributed-sensing techniques allow for measurement of physical properties such as temperature, pressure, strain and acoustics with increased accuracy and cost-effectiveness in geoscience applications.

Dr. Andres Chavarria, Technical Director – Oilfield Services for OptaSense, will present his paper “Offshore DAS VSP Applications and Long-Range Distributed Fiber-Optic Sensing” on Tuesday, March 10.

04 Feb 2020

EGYPS – Egypt Petroleum Show | February 11-13, 2020 | Egypt International Exhibition Center

Visit OptaSense in Hall 2 Stand 2E59

OptaSense will be participating in the 2020 Egypt Petroleum Show (EGYPS), February 11-13 at the Egypt International Exhibition Center. We’ll be joining with our partner, HitekNOFAL Solutions to showcase our fiber-optic monitoring solutions for pipeline monitoring, as well as perimeter and intrusion detection.

Register to visit the exhibition here.

03 Feb 2020

OptaSense opens new offices to meet growing Canadian market

OptaSense Calgary Office

Calgary – OptaSense, a QinetiQ company, a world leader in fiber-optic-based acoustic sensing, recently announced that it has expanded its Canadian presence in order to better serve its growing business in the country.

The company, which provides industry leading monitoring services in the upstream and midstream oil and gas businesses, recently moved its location in Calgary, Alberta.  The new facility is located at 999 57th Ave NE, next to Calgary International Airport and AB Highway 2. The increase in office, lab and shop space supports OptaSense’s growth of its engineering, field and service teams to support the expanding Canadian market.

Additionally, a satellite sales and support office has been opened in the heart of downtown Calgary to better serve OptaSense’ s expanding customer base in that area.  The new downtown office, located at 350 7th Ave SW, Suite 2900, provides ready access to support our customers.

Tony Meszaros, Managing Director for Oilfield Services, believes the two new locations demonstrate OptaSense’ commitment to its customers and the Canadian market, “Both new facilities provide expansion for not only our oil and gas services, but for the entire OptaSense fiber-optic sensing portfolio. Canada represents a tremendous opportunity and with these new locations, we are better positioned to meet the needs of the market.”

About OptaSense

OptaSense is a wholly-owned subsidiary of the QinetiQ Group.

It is a platform technology which has applications in a number of markets, including infrastructure security where the technology is already in use to monitor 25,000 km of assets, principally providing leak detection and third-party intrusion detection for oil and gas pipelines.

OptaSense is the world leader in Distributed Acoustic Sensing and operates in 40 countries globally across multiple industries including Oil & Gas, Defense & Security, Transport and Utilities.

19 Jun 2019

OptaSense Awarded Key Pakistan Pipeline and Producing Facility Perimeter Intrusion Detection Project

OptaSense, a QinetiQ company, a world leader in fiber-optic-based acoustic sensing, was recently awarded a key pipeline and gas producing facility /central producing facility perimeter intrusion detection system (PIDS) project by the pipeline and facility operator.

Having successfully installed the first pipeline protection system of its kind in Pakistan on a pipeline network in the Khyber Pakhtunkhwa Province of Northwest Pakistan, the operator selected OptaSense to follow up the initial procurement with another project that covers the Mardankhel west pipeline and wells, also located in the same province.

Building on the success of the Makori East pipeline network protection project, and utilising the existing fiber-optic infrastructure already in place, OptaSense will install a second intrusion detection system to protect the pipeline right-of-way from third party intrusion (TPI), covering the entire Mardankhel Pipeline network, as well as providing perimeter intrusion detection on the producing facility perimeter. This project included upgrading the existing system to the latest software version and integrating a new CCTV system covering the producing facility perimeter, enabling cross-cueing of the CCTV system to the respective alerts.

Jeff Williamson, Managing Director of OptaSense’s Infrastructure Security Monitoring (ISM) division stated “Not only is this the first project with our regional partner, but this is the first of its type in Pakistan. It will provide the customer with a secure pipeline and ensures a safe corridor to operate in. We hope that this provides a benchmark in countries where pipeline hot taps are wide spread.”

About OptaSense

OptaSense is a wholly-owned subsidiary of the QinetiQ Group

It is a platform technology which has applications in a number of markets, including infrastructure security where the technology is already in use to monitor 30,000 km of assets, principally providing leak detection and third-party intrusion detection for oil and gas pipelines.

OptaSense is the world leader in Distributed Acoustic Sensing and operating in 40 countries globally with operations across multiple industries including Oil & Gas, Defence & Security, Transport and Utilities.


17 Aug 2018

OptaSense earns “Qualified Supplier” certification for North Sea oil and gas market

OptaSense recently earned the designation “Qualified Supplier” by Achilles JQS, the leading industry initiative for pre-qualifying suppliers in the Nordic market. This prestigious designation ensures that buyers in the North Sea oil and gas market can trust OptaSense to provide reliable service that meets all Nordic environmental and regulatory requirements.

13 Jul 2017

Real-time Cluster Efficiency

Distributed fiber optic sensing for uniform fracture stimulation

Evaluating stimulation performance and well spacing early in development can increase a projects Net Present Value. This is especially true when developing stacked intervals.  For example, studies have shown that plug-and-perf completions often produce under-performing perforation clusters and undesired inter-well communication.

To address under-performing perforation clusters, operators are combining Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS)measurements to calculate the amount of fluid and proppant placed in each cluster on the fly to enable optimized decision-making throughout a project ensure more effective fracturing on current and future wells.

Recent observations from fiber optic DAS and DTS indicate that a majority of treatment volume is limited to only one or two dominate clusters near the heel-side of a treatment stage—leaving the remaining stage clusters under stimulated.

With a large majority of perforation clusters failing to contribute to production, you can’t help but ask: Where’s my proppant going and why?

Assessing cluster efficiency, fluid distribution and diverter effectiveness

There are many possible reasons for uneven reservoir stimulation, such as stress shadowing interference between fractures, local heterogeneity, the effectiveness of zonal isolation between stages, stimulation design (pumping schedules and fluid/proppant selection), and the variation in natural fracture systems surrounding the well.

Fiber optic monitoring, such as DAS and DTS can be used to assess cluster efficiency, fluid and sand distribution and diverter effectiveness.

On a recent spacing pilot in the Anadarko Basin, home to several stacked interval reservoirs, a five-well project equipped with OptaSense Distributed Fiber Optic Sensing offered another explanation for the heel-side bias. For this project fiber optic derived DAS and DTS measurements provided the operator an opportunity to monitor fluid movement during fracture stimulation and warm-back before the well was produced.

Monitoring distribution

During treatment, acoustic and temperature data confirmed inadvertent diversion away from toe-side clusters, and acceleration of the already-dominant heel-side clusters. Using algorithms applied to DAS data, proppant volumes per cluster were calculated revealing highly uneven proppant distribution among multiple clusters even when fluid is uniformly distributed

The DAS measurements captured in this pilot project suggested a strong heel bias was present in a majority of stages. The uneven distribution, caused by interference between adjacent fractures within a given stage and from preceding fracture stages, resulted in a consistent geometric predominance for fracture growth toward the most heel-ward perforation cluster.

A variety of completion variables, such as perforation designs, fluid systems, diverter and proppant size, were tested to identify the optimal treatment for improved fluid distribution.

Simulating distribution

Using these measurements, the operator used calculated proppant placement to monitor diversion efficiency in real-time during the fracture and took action to modify the treatment, which resulted in more even fluid and treatment distribution. After modeling the improved distributions derived from fiber optic monitoring, a new well completion and stimulation design resulted in more equal fracture heights and half lengths, as well as increased the overall effective fractures in the wellbore.

Multiple optimizations in pressure pumping strategy were discovered during the variable testing using real-time DAS and DTS. The pumping schedule was altered to test different rations of slick water and high viscous fluids, ratios in proppant sizes and concentrations of proppant within the various fluids.

Optimizing distribution

Using DAS and DTS to estimate fluid and proppant placement enabled the operator to identify the root problem and implement an effective proppant and fluid treatment (aligned with an optimized pressure pump schedule) that mitigated the uneven stimulation. The result, improved cluster efficiency and more uniform proppant/fluid distribution on current and future stages and wells.

15 Dec 2016

Enabling Cost-Effective Sweep Efficiency with DAS-VSP

Offshore brownfield exploitation generally involves operating in remote, environmentally sensitive areas that have geologic basins with complex overburden, structure and stratigraphy.

In these geologically challenging areas, Ocean Bottom Node (OBN) seismic acquisition is the technology of choice for a number of reasons; the most important being its ability to capture a high quality seismic image, which is critical for characterizing time-lapse response of the reservoir.

Due to the high acquisition cost, many mature reservoirs using an OBN approach for time-lapse imaging are surveyed several years apart, resulting in the missed opportunity to effectively manage and understand the reservoir.

To eliminate this risk, a supermajor operating in the Gulf of Mexico contacted the OptaSense team with the goal of identifying a low-cost alternative that would enable comparable or better quality seismic surveys at more frequent intervals.

Rethinking borehole seismic

Technology plays crucial role in providing the information to make sound exploration decisions. Given the complexity and high cost of deepwater development, there is great value in being able to identify the best spots to drill wells and manage production methods for field exploitation. This skill hinges on generating an accurate picture of the subsurface. Seismic technology lies at the heart of this process and was a key research priority for our client.

Vertical Seismic Profiling (VSP) has long been considered a possible solution for deepwater seismic imaging; however, high cost and practicality have made it unfeasible for many operators. Since the introduction of Distributed Acoustic Sensing (DAS) VSP technology, these concerns have essentially been eliminated.

Putting DAS to the test

Concept testing for the low-cost, on-demand DAS-VSP solution included several aggressive objectives, one being surveying reservoirs lying below thick salt formations which are notoriously challenging to image. Additional objectives included demonstrating repeat DAS acquisition using multimode fiber, acquiring DAS on active production and injection wells, and providing quick on-demand service for time-lapse monitoring of sweep efficiency.

To meet these objectives, OptaSense recommended running their DAS-VSP borehole seismic acquisition service, capable of acquiring 2D, 3D and 4D VSP data, and the fourth generation ODH-4 DAS interrogator unit (IU) for its unmatched imaging and measurement performance.

The ODH-4 provides a 6 dB improvement in signal-to-noise ratio over its predecessor—delivering the highest fidelity VSP measurements available. In addition to higher quality seismic imaging, the ODH-4 offers increased sensitivity, finer spatial sampling (1.02m) and finer spatial resolution of (4.02m gauge length) to capture high-caliber image resolution.

Subsalt imaging

Oil and gas is commonly trapped subsalt, or near salt flanks.Incidentally, imaging near and below the large salt structures is naturally problematic for any surface or OBN seismic program. One of the best known methods to properly image these areas is a VSP survey, which enables access to these obscure locations. However, these wellbores commonly have high deviation and high entry to access costs, making the use of conventional geophones unfeasible.
The ODH-4 IU instead transformed the operators existing fiber optic cable attached to production casing into an array aperture to acquire VSP data across the entire wellbore.

Multimode fiber acquisition

By retro-fitting our DAS technology to pre-existing multimode fibers, OptaSense provided permanent, on-demand DAS-VSP access at no extra cost to the operator. Although DAS was originally developed for single-mode fibers, most legacy fiber optic installations are multimode.

By continuously pioneering the evolution of DAS technology, OptaSense has proven quality DAS measurement can be acquired on either single-mode or multimode fiber—enabling on-demand acquisition of quality seismic surveys from wellbores with existing fiber.

VSP acquisition on active production and injection wells

With OptaSense DAS-VSP borehole seismic acquisition service, the operator successfully acquired VSP data on actively producing and injecting wellbores during acquisition operations. Such a practice would be unthinkable with geophones.

In some cases, a mature field may not have suitable placement for, or the existence of, an observation well. This can impact an operator’s ability to monitor production, as well as optimize future well placement. Our DAS-VSP eliminates the requirement of observation wellbores for VSP imaging, while providing on-demand, direct monitoring of production and injection zones.This ensures operators receive the subsurface insight required to control current operations and optimize future placement of injector and producer wells.

OptaSense DAS-VSP also provides the ability to acquire data on active wellbores without shutting in operations—resulting in greater VSP imaging coverage at favorable economic costs.

On-demand 4D time-lapse

Due to cost, 4D VSP acquisition at shorter intervals may not be feasible. However, the OptaSense DAS-VSP service is flexible, quickly mobilized and offers favorable economics for repeat acquisition monitoring.
Through the use of our DAS-VSP 4D time-lapse service, the operator effectively monitored conditions throughout the reservoir over time—increasing recovery, optimizing cost, reducing risk and extending the life of the field.

Unmanned VSP services

Manned operations for recording instruments can amount to significantly increased risk and cost depending on the duration and location of the program. Through the use of a suitable internet connection OptaSense can provide unmanned VSP services through remote monitoring of OptaSense equipment and data. This significantly reduced cost and HSE exposure for our client by reducing lodging, substance and day rates for an onsite operator, in exchange for a daily remote monitoring fee.

Exceeding expectations

The quality of the DAS-VSP acquired using our ODH-4 IU surpassed our client’s expectations. This included data collected on multimode fiber, actively producing and injecting wellbores and those positioned subsalt.

Imaging objectives for 4D reservoir monitoring continues to be successfully met and our client is looking forward to expanding DAS-VSP service for regular time-lapse monitoring of their asset. In just a short period of monitoring, our client is moving forward with DAS-VSP service as an integral part of sustainable field development. They have realized added value with the service’s seamless application and the capability to remotely monitor the equipment and program. Our client highly advocates the installation of fiber optic cables for new offshore wells, and utilizing existing fibred wells to take full advantage of DAS for VSP acquisition.