Fluid Volume

Before Stimulation - 35 bbls/ft
After Stimulation - 50 bbls/ft

Proppant Value

Before Stimulation - 500 lbs/ft
After Stimulation - 1,000 lbs/ft

Stage Spacing

Before Stimulation - 220 ft
After Stimulation - 110 ft

COMITT's Solution

COMITT proposed the use of our patented EXCITE System to refracture the accessible portions of the lateral. Given the 220ft distance between the original stages it was proposed to add perforations between the original stages to access untreated formation and to place proppant fracture treatments into the newly added perf clusters. Additionally, two more perf clusters were added above the last original stage to extend the producing section of the lateral. Original perforations were to be treated with acid to clean suspected wellbore damage.

Formation Depth

Downhole Temperature

Production Increase

Sequence of Events

New perforations were added to the wellbore by a separate explosive perforating run on wire line. Once the perforations were placed, the EXCITE System was RIH on conventional 2-7/8” tubing. For each stage to be treated, clean fluid was pumped at 2 BPM to fill the tubing and pump rate was then increased to the calibrated activation rate of 3 BPM to activate the EXCITE System. A positive pressure indication was seen on surface when the tool activated (see example chart). Pump rate was increased and the stimulation program for each stage was pumped. Following each treatment an ISIP reading was performed before the EXCITE System was reset and moved to the next stage to be treated. A screen out was noted during for Stage #1. To clear tubing the EXCITE tool was first reset by reducing tubing pressure. Clean fluid was then pumped down the backside of the tubing string and the proppant laden fluid was reverse circulated out of hole before the EXCITE tool was pulled to the next stage. Each new stage in the well was successfully pin-point fracture treated. The highest proppant volume placed into a single fracture was 170,000 lbs at rates up to 17 BPM and proppant concentrations up to 4 ppa. The two old stages were each treated with 1,500 gallons of acid.

Well Results

The pressure chart below shows a typical treatment where the tool was activated, treatment was pumped, an ISIP reading was taken, and the tool was reset. For the proppant stages, the treating pressure was very similar to the average treating pressures experienced in the original frac job for the well, clearly indicating that unstimulated rock was being treated. The ISIP observed after each treatment was also similar to the ISIPs observed in the original completion, further indicating treatment of the previously untreated formation.

Well Response

Following the treatment, wellhead pressure had increased to 1,400 psi, compared to being pumped off and zero psi pre-treatment. Once the well was put online, oil production increased by a tenfold as compared to the pre-job production rate. Given the casing collapse issue right above the original stage 8, the increase in production came from only about 20% of the lateral. Further extrapolation of the production results yields that a re-frac of the entire wellbore likely would have brought production to a higher level than what the well originally came in at.

Conclusion

The tool was used to perform an industry-first pin-point re-frac of an existing plug & perf well. The customer had 100% product placement control for each of the treatments which were placed. During the job, a screen out was easily mediated by the use of the patented hydraulic activation/deactivation feature of the system. A production increase of 10 times the pre-job production proved the economic attractiveness to re-fracs in general and the pin-point approach as allowed by the system in specific.

(Zone #1 Treatment Chart)

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