Deeprop®, Delaware Basin Trial Results in a 23% Production Uplift
The Delaware Basin trial results were an extraordinary success.
The trial wells easily exceeded the hurdle rate of >10% production uplift.
The operator is looking to expand the trial to include a larger number of wells.
This operators DEEPROP® trial was designed to minimize the bias from inherent geologic, drilling and completion variability. Despite the amount of design, planning and controls put in place for this trial, the operator set a 10% production uplift hurdle to conclusively determine project success. The combined production uplift from the wells treated with DEEPROP® was 23%, easily exceeding hurdle rate, generated an additional 120,000BOE, and created a 700% return on investment on the cost to incorporate DEEPROP® into their design. This operator is now looking to expand the trials to a significantly larger series of tests.
Many variables play a role in well performance in unconventional shale plays – in a broad sense they are the variability in geology, how the well was constructed, and how the well was completed. The methodology employed by the operator for the trial presented below was to minimize the impact these variations would have on interpreting the production impact of using DEEPROP® to enhance production in their Delaware Basin Play.
To achieve this, the operator selected an area of virgin reservoir – to avoid depletion effects from parent wells. They drilled two, 2-well pads to both avoid inside/outside bias, and the possibility of interference effects between wells. One pair of wells was set in the Wolfcamp A, and one pair of wells was set in the Wolfcamp B. The operator also constructed the wells the same, i.e. same lateral length, same landing depth, etc; and kept the completion design the same, i.e. same number of stages, same stage spacing, tonnage etc.
Despite all of these controls to eliminate the inherent variability in horizontal multi-frac well performance, the operator set a 10% production hurdle rate. If the production uplift was less than 10%, the test results would be inconclusive; however, if the production uplift exceeded 10%, it was deemed to be a significant enough production uplift to conclusively say that DEEPROP® was providing the production enhancement.
It is worth noting that the operator used SPE-194340 to estimate the extent of their pre-existing and stimulated secondary fracture network; this led the operator to pump DEEPROP® as 5% of their proppant tonnage in the test wells to ensure that they completely filled the stimulated micro-fracture network; typically we recommend 2.5% as a starting point.
6-Month Production Update
The figures below are the 6-month production update for the DEEPROP® trial. Despite being drilled and completed at the same time, there are differences in the producing periods because the wells were shut in or curtailed periodically due to emission issues. The DEEPROP® well in the Wolfcamp A, also lacked cement integrity for approximately 35% of the lateral but is still the best producer. The black, dashed line represents the type-curve for this area.
Figure 1: Wolfcamp A, 6-month production DEEPROP® Trial
Figure 2: Wolfcamp B, 3-month production DEEPROP® Trial
At 6-months, the DEEPROP® well in the Wolfcamp A has produced 30% more than the type curve, and the DEEPROP® well in the Wolfcamp B has produced 21% more than the type curve; both DEEPROP® wells are outperforming their respective control wells. Below In figure #3, the operator also shows that the DEEPROP® wells have higher sustained casing pressures, and a higher productivity index versus the control wells. The final assessment of the trial would be made after 9 producing months.
Figure 3: Operator supplied plots.
11-Month Production Update
The results after 11-months were astounding, the DEEPROP® treated wells yielded 23% more production than the control wells, easily exceeding the hurdle rate set by the operator. Combined, the wells treated with DEEPROP® produced an additional 120,000 BOE, compared to the offsets without DEEPROP®. Monetized at a $35/bbl netback, the wells treated with DEEPROP® generated an additional $4.2MM in revenue for a cost of $0.6MM, or an ROI of 700% in less than 1-year.
This operator is currently looking to expand their trials to an area where they have a larger footprint and can incorporate DEEPROP® into a more statistically significant test.
Figure 4: Operator supplied 11-month production update.
If you’d like more information about DEEPROP®, or if you’d like to have a chat with us about how you can apply DEEPROP® in your play, get in touch with us at:
We’re also hosting a booth at URTeC, booth 4600 from July 26-28th! I would encourage you to stop by for a chat, we would love to meet you.