Clay Gaspar
Executive Vice President and Chief Operating Officer at Devon Energy
Thank you, Rick, and good morning everyone. As Rick touched on earlier, our team did a great job of meeting the first quarter operational targets through solid well productivity, effective cost management and the steady progression of upcoming development projects that will benefit us for over the coming quarters. Remember, we're focused not just on delivering the numbers for this quarter and year, but also de-risking opportunities for the coming years and also investing in R&D that will create value throughout the coming decade. We're making great progress on all three fronts. This positive start to the year, put us in great position to continue to build momentum throughout the course of the year and achieve our corporate objectives for 2023.
A significant contributor to the success in this quarter was our franchise asset in the Delaware Basin. As you can see on Slide 15, roughly 60% of our capital was deployed to this prolific basin allowing us to run a consistent program of 16 rigs and four frac crews in the quarter. With this level of drilling and completion activity, we brought online 42 new wells in the quarter, with the majority of this activity targeting high-impact intervals in the Upper Wolfcamp.
This focused development program resulted in another quarter of volume growth year-over-year with oil representing 51% of the product mix. While we had great productivity across our acreage position, our performance during the quarter was headlined by Exotic Cat Radar projects. This six well pad located in Lea County, New Mexico targeted a highly productive area with three mile laterals in the Upper Wolfcamp. Individual wells at Exotic Cat flowed at rates over 7,200 BOE per day. And well -- per well recoveries from this pad are on-track to exceed 2 million barrels of oil equivalent.
The flow rates from this activity rank among the very best projects, Devon has ever brought online in the basin. And lastly on this slide, another key event for us during the quarter was the resumption of operations at our Stateline eight compressor station. This was possible, thanks to the team's timely efforts in securing replacement equipment and the personnel to safely repair this critical facility. Although this repair work did temporarily limit our production in this part of the field during the quarter, we are confident that we resolved this issue and we do not expect any further disruptions of this nature. Furthermore, we also commenced operations at our Stateline 10 compressor station, providing us another 90 million cubic-feet of throughput and even more flexibility in the region going forward.
Turning to Slide 16. As I look-ahead to the remainder of the year, our Delaware asset is well-positioned to build upon the solid results we achieved in the first quarter. Overall, with the 200 wells that we plan to bring online this year in the Delaware, we expect well productivity to be very consistent with the high quality wells we brought online over the past few years. And for context as shown on the chart to the right, this level of well productivity, would not only positioned Devon among the top operators in this world-class basin, but would also surpassed the performance of other top shale plays in the U.S., by a noteworthy margin. This impressive well performance, coupled with a long runway of high value input inventory, further underscores the competitive advantage and the sustainability of our resource base in the Delaware Basin.
Turning to Slide 17. Another asset. I'd like to spend some time on today is the Eagle Ford, which is our second highest funded asset in 2023. Over the past few years, we've taken a disciplined and scientific approach to refine the next phase of development in this prolific field through thoughtful and measured appraisal work. The momentum generated from these learnings is evident in our current capital program, where we are pursuing tighter infield spacing and have active refrac program. With the goal to affect -- efficiently sustain a steady production profile and harvest significant free cash flow.
This year we plan to spud over 90 wells, with the majority of this drilling focused on redeveloping acreage with much tighter spacing than originally conceived when we first entered the play a decade ago. We attribute this infilled opportunity to high reservoir pressure, our fractured network that heals quickly and low but consistent permeability. This unique combination allows us to pursue significantly tighter spacing with redevelopment activity targeting 16 to 20 wells per unit across multiple landing zones in the Eagle Ford.
In addition to the benefit of oil-weighted recoveries that are projected to exceed 0.5 billion barrels per well. Our ability to leverage this existing infrastructure in the play, also bolsters the returns. These unique and favorable reservoir characteristics in the Eagle Ford, provides us with many years of highly competitive drilling inventory. The team has also made steady progress on our refrac program in the Eagle Ford, achieving consistent successful and re-stimulating the productivity of older wells. To-date, we have roughly 30 refracs online that have successfully accessed untapped resource, resulting in an immediate uplift to the well productivity that has expanded per well reserves by more than 50%. In 2023, we plan to execute around 10 refracs, and we've identified several 100 high-return candidates across the field to pursue in the future.
While we have made significant progress on improving recoveries through infill spacing and refracs, we believe there is still meaningful resource upside in this play. A catalyst to help us accelerate our learnings in this area is our ZGABAY pilot in DeWitt County, which is supported by a grant from the U.S. Department of Energy. The objective of this grant is to fund as field study and create an underground laboratory to improve the effectiveness of shale recoveries by testing new monitoring techniques for both initial stimulation and production, as well as collecting critical data to enhance recoveries via re-fracking and EUR. While we're still in the early stages of gathering and interpreting the data from this project, we have already incorporated learnings into the date -- into our day-to day operations. These learnings will enable us to optimize recovery of resource and not only in the Eagle Ford, but across our broader footprint in the U.S. I expect to have more positive updates on this topic in the future.
And finally on Slide 18. I'm also excited to talk about the positive results we're seeing delivered on other key assets across our portfolio. As you can see on the graphic to the right, over the past year, we've done some good work to opportunistically build-up operating scale in these areas and increase the production by 9%. The main factors that drove this growth were our Dow JV partnership, which helped us regain operational momentum in the Anadarko Basin, the Rimrock acquisition in the Williston and the quality of assessment work we've done in the Niobrara oil play in the Powder River Basin. That has helped us build for the future.
In addition to solid production growth, this diversified group of assets is on pace to generate a meaningful tranche of cash flow that we can deploy to other key strategic priorities, such as the return of capital to shareholders. I appreciate the team's hard work and the effort that goes into delivering near-term free cash flow and also de-risking valuable future inventory.
With that. I will turn the call over to Jeff for a financial review, Jeff.
