Slick Water and Hybrid Fracs in the Bossier: Some Lessons Learnt

Sharma, Mukul M.; Gadde, Phani; Richard, Sullivan; Richard, Sigal; Robin, Fielder; David, Copeland; Larry, Griffin; Leen, Weijers

doi:10.2523/89876-ms

Cited by 12 publications

(6 citation statements)

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“…In this case, the record is from data presented by Sharma et al (2004), and is presented in terms of microseismic locations in Figure 1. The data is recorded on one channel from a triaxial geophone, of which there are 12 geophones in the downhole string -meaning that this data is 1 of 36 possible channels to examine.…”

Section: Application To Hydrofracturingmentioning

confidence: 99%

“…wellbore surveys and geology) the hypocenters are able to map the evolution of a hydrofracture treatment through a given volume and thus provide engineers useful information on the treatment effectiveness, the position, growth and distribution of new fractures, and whether existing fault zones have been intersected and stimulated. Figure 1 shows microseismic locations re-processed from data presented by Sharma et al (2004), where fault communication between formations is observed. Microseismics is therefore playing a key role in engineering and evaluating fracture networks in a wide variety of regimes including petroleum reservoirs, engineered geothermal systems and block-caving mines.…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Using continuous microseismic records for hydrofracture diagnostics and mechanics

Pettitt¹,

Reyes-Montes²,

Hemmings³

et al. 2009

SEG Technical Program Expanded Abstracts 2009

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Using continuous microseismic records is a novel technique for better understanding the mechanics of the fracture network evolution during a hydrofracture treatment, and to provide a tool for diagnostic evaluation of recorded microseismic data. Hydrofracture stimulations are widely used during well completions to optimize production volumes and extraction rates in petroleum reservoirs, enhanced geothermal systems and block-caving mines. Microseismic monitoring is now becoming a standard tool for evaluating the position and evolution of a given treatment, principally by source locating microseismic hypocenters and visualizing these with respect to the treatment volume and infrastructure. The continuous microseismic amplitude record includes the full history of the seismic energy response of the rock mass recorded at a given geophone. We present case studies illustrating the use of this technique for supplementing microseismic locations to better understand the evolution of the fracture treatment, and to diagnose the condition of a given data set, so as to design criteria for more effective processing of the discrete microseismic events.

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Section: Application To Hydrofracturingmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Using continuous microseismic records for hydrofracture diagnostics and mechanics

Pettitt¹,

Reyes-Montes²,

Hemmings³

et al. 2009

SEG Technical Program Expanded Abstracts 2009

View full text Add to dashboard Cite

show abstract

“…Hydraulic fracture stimulations are performed as waterfracs, gel-proppant fracs, or a combination of both called hybrid fracs (Sharma et al, 2004) The procedures are well known in the hydrocarbon industry (Shaoul et al, 2007a, b) as well as in the HDR technology Baumgärtner et al, 2004;Schindler et al, 2008). However, the application for geothermal reservoirs requires a technique that is able to produce considerable higher amounts of fluids than the ones required for production of hydrocarbon reservoirs.…”

Section: Hydraulic Stimulationmentioning

confidence: 99%

Enhancing Geothermal Reservoirs

Schulte

Zimmermann

Vuataz

et al. 2010

Geothermal Energy Systems

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“…In many low permeability gas reservoirs aqueous fracturing fluids are used due to their cost advantage and safety considerations (5,6) . Furthermore, the chemistry involved in providing a wide variety of predictable fluid properties is more easily understood for aqueous fluids.…”

Section: Introductionmentioning

confidence: 99%

Completion Operations in Low Permeability Deep Basin Gas Reservoirs: To Use or Not to Use Aqueous Fluids, That is the Question

Coşkuner

2006

Journal of Canadian Petroleum Technology

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Many tight gas formations are water-wet and undersaturated where the initial water saturation in the reservoir is less than the capillary equilibrium irreducible water saturation. Using aqueous-based stimulation and workover fluids causes water to be trapped in the near wellbore region, thereby significantly impairing the ability of gas to flow. Therefore, hydrocarbon fluids are better suited for completion operations in such reservoirs. Laboratory data revealing the sensitivity of one such formation to aqueous fluid invasion are discussed and actual field examples are provided in three different formations. Introduction As the oil and gas industry matures and known reserves continue to be depleted, the focus moves towards more challenging environments. One such environment is the Deep Basin area of West Central Alberta where vast reserves of natural gas and associated liquids are present in a number of low permeability reservoirs(1). Similar areas also exist in the U.S., such as the Powder River Basin, Permian Basin, and the Green River Basin. In situ effective gas permeabilities in such reservoirs are in the 0.1 mD range or less. It should be noted that while routine core measurements in the laboratory may indicate permeabilities of up to 1 mD for such reservoirs, the effective gas permeability in the reservoir will be significantly less(2, 3). Although horizontal wells are being used with increasing frequency in exploiting such reservoirs, the vast majority of the wells drilled are vertical wells in the Deep Basin. This is mainly due to the differences in the cost of drilling. A typical horizontal well can be as much as two to four times more expensive than a vertical well for such deep targets. Also, because most horizontal wells are completed barefoot in tight gas reservoirs, the drilling induced damage becomes quite important for the performance of these wells. Therefore, it is critical that a suitable drilling fluid be used in drilling horizontal wells. This was discussed in an earlier article(4). The gas flow rate from a vertical well can be maximized by stimulation. Vertical wells in tight gas formations are usually stimulated by hydraulic fracturing after drilling. Hydraulic fracturing is accomplished by pumping a large volume of fluid mixed with additives and a solid proppant (usually sand) into the formation at high injection rates, cracking the reservoir rock. The fluid is used as a carrier so the proppant can be pumped, and once the proppant has been placed in the fracture, the well is usually flowed back to a tank to recover the carrier fluid. The permeability of the proppant is very high. However, some of the carrier fluid will be imbibed into the freshly exposed matrix rock and remain in place. Depending on the characteristics of the fluid, the permeability of the fracture face may be impaired. The same can also be said for fluids used in workover operations as well. In many low permeability gas reservoirs aqueous fracturing fluids are used due to their cost advantage and safety considerations(5, 6).

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Slick Water and Hybrid Fracs in the Bossier: Some Lessons Learnt

Cited by 12 publications

References 0 publications

Using continuous microseismic records for hydrofracture diagnostics and mechanics

Using continuous microseismic records for hydrofracture diagnostics and mechanics

Enhancing Geothermal Reservoirs

Completion Operations in Low Permeability Deep Basin Gas Reservoirs: To Use or Not to Use Aqueous Fluids, That is the Question

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