STIMULATION

DeepQuest® HT service enables fracture stimulation of high pressure and high temperature reservoirs without exceeding the safety limits of surface treating equipment and wellbore tubulars. The high density fracturing fluid used in the service can help overcome these HPHT stimulation challenges, both onshore and offshore:

• Bottomholetemperaturesupto375°F(191°C).

• Bottomholetreatingpressuresinexcessof15,000psi.

• Formationstressgradientsabove0.95psi/ft.

• Limitedavailabilityof20,000psifracturingequipment.

TheabilityofDeepQuestHTservicetoreducesurfacetreatingpressurecaneliminatetheOperator’sneedandcostsforobtaininghigher-pressureequipment.Lowersurfacetreatingpressuresalsotranslateintosaferoperatingconditions.

DeepQuest® HT Fracturing Service for HPHT ReservoirsPerforms at High Temperature and Pressures Without Exceeding the Safety Limits of Surface Equipment

Fig. 1 – Example of surface treating pressures using DeepQuest HT service vs conventional high temperature fracturing fluid at 20,366 psi bottomhole treating pressure. Notice that with the conventional fluid, surface treating pressure approaches the operating limit of surface equipment at only about 15 bbl/min rate.

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Comparison of Wellhead Pressure of a Conventional Crosslinked Fluid vs DeepQuest HT Fluid

DeepQuest HT Fluid - 12.3 lb/gal

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For both offshore and land applications, DeepQuest HT service can help optimize fracturing treatments of wells completed in deep, high pressure, high temperature formations. The fluid system is well suited, for example, for the hot Miocene formation in the GOM and in formations in South and East Texas, the Middle East and Indonesia.

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DeepQuest HT fluid is a delayed crosslinked fracturing fluid with rheology properties comparable to conventional high temperature fracture fluids.

The fluid can be used in wells with bottomhole static temperatures (BHST) of 300° to 375°F (149° to 191°C).

For lower temperature wells with BHST of 80° to 300°F (27° to 191°C), lower-temperature-range DeepQuest fluid provides excellent performance.

DeepQuest HT Fluid Properties

DeepQuest HT service harnesses the power of gravity to reduce the surface treating pressure required to achieve adequate fracturing pressure (Fig. 1). The typical specific gravity for an aqueous frac fluid is 1.00 to 1.04; the specific gravity of DeepQuest HT fluid is 1.14 to 1.50.

STIMULATION

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Case History

DeepQuestSM HT Service Helps Unlock Hot, Tight Gas Reservoir Saudi Arabia – DeepQuest HT service was used recently when Saudi Aramco faced a high-pressure and high-temperature (HPHT) stimulation challenge in a new field.– 375°F (191°C) reservoir temperature and more than 15,000 psi required for fracturing. The challenge for Saudi Aramco went beyond this well. Developing an innovative way to frac under these conditions – HPHT tight gas sandstone – was crucial to stimulating and proving the reserves of the tight gas formations in northwestern Saudi Arabia.

Wells completed in the Lower Tertiary and Miocene formations in the Gulf of Mexico can present challenges in terms of high temperatures and pressures. DeepQuest HT service can help optimize completions in these areas.

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For more information about how DeepQuest® HT service can add real value in HPHT fracturing treatments, contact your local Halliburton representative or email stimulation@Halliburton.com.

The Halliburton Saudi Arabia Production Enhancement team worked with experts in Duncan, Oklahoma, and Houston to develop the DeepQuest HT fluid system to perform under these extreme conditions.

The Saudi Aramco job was performed flawlessly by pumping 16.4 barrels per minute at 21,000-psi bottomhole treating pressure. As specified in the design, Halliburton’s Production Enhancement team pumped 80,000 gallons of the gel system and placed more than 150,000 pounds of proppant.