Success Stories

Through Tubing Inflatable BP For Water Shutoff Lead to 43% Production Increase and 80% WC Reduction

The candidate well was a development well located in Khyber Pakhtunkhawa Province of Pakistan. It was completed as commingled gas condensate producer from Limestone (overlying) and Sandstone (underlying) formations. Well was brought online in 2010 and in 2013, PLT survey revealed 90% WC production from lower sandstone formations.

Initial attempts were made to set the blanking plug in the lower nipple profile with slickline to abandon the production from the lower zone. However, due to a damaged nipple profile the operation could not be completed.

Sprint recommended to set a TTIBP via CT in 7" Liner at 3,738 m, to isolate the water production from lower formation and to allow stimulating the upper Limestone formation with SRA-15 acid system.

Stimulation of Highly Fractured Limestone Reservoir Using NDA-S Non-damaging Diverting Acid Leads to a 30% Production Increase

The Candidate was an appraisal well located in Khyber Pakhtunkhawa Province of Pakistan. The objective of the operator was to stimulate the upper limestone formation that was identified to have a high skin without the treatment to penetrate the lower producing formation.

The Well was a micro fractured high-pressure gas condensate producer and treatment fluid diversion was a key factor for uniform zonal coverage and job success. Additionally, the main challenge was the need to isolate the exposed lower sandstone formations prior to performing the treatment in the upper fractured limestone formation to avoid unpredictable deposition.

However, mechanical isolation could not be used due to a limitation in the nipple diameter. Accordingly, a treatment was designed to first place an NDP Non-Damaging Diverting Pill as a diverting platform across the lower sandstone formation then treating the main formation using SRA-15 and NDA-S (non-damaging diverter) to evenly stimulate the highly fractured limestone reservoir. The result was a 30% production increase.

Multi-Zone Stimulation Using Nitrified Alcoholic SRA-5 and SRA-15

The candidate well was a development well drilled in a Sindh oilfield in Pakistan. The well targeted three different gas producing zones each of these zones are separated by a packer and can be accessed through an SSD. The well was completed using a 5" tubing down to 2,588 m and with PBTD of 2,707 m.

The three producing zones were:

Zones Perf

interval (m)

WHFP (psi)

Zone -1

2315 - 2393.5


Zone - 2

2474 - 2567


Zone - 3

2588.5 - 2637


It was required to stimulate Zone-2 & Zone-3 and enhance its production by eliminating any formation damage. A matrix stimulation treatment using nitrified alcoholic SRA-15 proved to effectively increase the production of tight limestone and sandstone formations in wells with higher water affinity. An energized alcoholic SRA-15 treatment was used for stimulating two sandstone zones in the same well, resulting in unprecedented production enhancement with an increment of 3.7 folds in one zone and of 2.4 folds in the second, and total awarding production increment of 8.72 MMSCFD gas.

Tubing Patch Installation using Straddle Packers and Coiled Tubing in Horizontal Wells

The candidate well was the second extended reach horizontal well in Pakistan. The well was drilled in Sindh province and had a horizontal departure to vertical depth ratio of more than 1.5. The main target of the well was (SML) formation and it was drilled as an 8 1/2'' hole and a 7'' liner was run and set at the depth of 1,700m leaving an OH section of 243m below liner shoe. A combination of 4-1/2'' and 5-1/2'' old tubing (above SSSV) were installed.

Well was later stimulated using Sprint's recommended SRA-15 and NDA-S systems and tested at 20 MMSCFD. During production, communication was observed in tubing annulus above SSSV, this was later confirmed using sonic logs to be at depth between 31.5m to 33.5m from RTKB.

A "16 ft Tubing Patch" was installed above SSSV using a hydraulically set thru tubing straddle packers run on coiled tubing. The tubing patch successfully isolated the leak in the tubing and the job helped the production company to handle similar tubing damage without the need to pull the completion and loose well production.

Alcoholic SRA-15 Acid System Brings Back on Production Gas Well

The candidate well was a development well completed with a 7" Tie-back production liner down to 1,820 m and a 4.5" Liner from 1,758 m to 2,212 m. The well was producing from a carbonate cemented Sandstone formation through a perforated Interval from 1,846 m down to 2,166.5 m. The total net perforation interval was 197.5 m.

Due to low reservoir pressure (less than 500 psi), work-over on well was performed using inhibited OBM System and Nitrogen kickoff (s) were performed to bring back well on production. However, during well cleanout operation it was found that the bottom perforations were producing sand at a rate beyond surface separation facility capacity. Accordingly, it was decided to plug the bottom perforations using a bridge plug and to dump cement on top of it prior to performing a well stimulation job through Coiled Tubing. The plug was set at 2,101m and cement was dumped on top up to the depth of 2,103 m.

After the isolation of sand producing zone, the net perforated interval was reduced to +/-100m. And production reduced from 10 mmscf/day to merely 4.9 mmscf/day. A Matrix Stimulation treatment using SPRINT'S nitrified Organic Solvent and Alcoholic SRA-15 acid system in the sandstone reservoir resulted in a 60 % increase in production.

Sprint SRA-7.5 Used to Effectively Conduct Perforation Wash and Matrix Stimulation in Carbonate Cemented Sandstones

The well X-Deep-01 is an exploratory well drilled in Khyber Pakhtunkhwa and Mianwali District of Punjab, Pakistan. The well was spud on 18-Feb-2015 and drilled to 5669 m (18599 ft) to target Lumshiwal/Hangu (Sandstone) and Samanasuk/Shinawari (Limestone) Formations.

X-Deep-01 was producing from two different formations, the first was a carbonate cemented sandstone (Hungu/Lumshiwal) and the second was a Limestone  (Samanasuk/Shinawari). The client's objective was to stimulate the sandstone formation without causing sand deconsolidation. No stimulation was required for the Limestone (Samanasuk/Shinawari) since it had a negative skin.

The use of the weak SRA acid system with high loading of chelating agent helped the successful stimulation of the high carbonate content sandstone formation in the well X-Deep-01. Following the Stimulation job, the well production was increased by 20% yielding an oil production increase from 1200 to 1440 bbl and a 1.09 to 1.3 MMScf of gas per day.