CO2 Pilot Design and Water Injection Performance in the Naturally Fractured Spraberry Trend Area, West Texas

Schechter, .S.; Putra, E.; Baker, R.O.; Knight, W.H.; McDonald, W.P.; Leonard, P.; Rounding, C.

doi:10.2523/71605-ms

Cited by 4 publications

(2 citation statements)

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“…The upper Spraberry typically begins at a depth of 7000 ft and has a gross thickness of approximately 200 ft. 3 In the 1960s a water injection program was initiated in the Driver Unit, but the lack of a strong production response resulted in a search for more effective ways to recover oil in the area. The lower Spraberry begins around 7500 ft and also only contains two layers of reservoir rock, each with an average permeability of 0.8 md.…”

Section: Introductionmentioning

confidence: 99%

Using Production History to Identify Acid Stimulation Candidates in the Spraberry Trend

Coulthard¹

2007

Proceedings of SPE Annual Technical Conference and Exhibition

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There are currently over 10,000 wells producing in the Spraberry field of West Texas. A substantial problem in the maturing field is scale buildup on perforations created by poor reservoir water quality. Spraberry operators matrix acidize wells to remove this buildup and increase production. However, operators lack a proactive method to determine acid stimulation candidates. Currently, wells are not stimulated until scale buildup causes flow to cease entirely. Through the analysis of 32 acidized wells in the Spraberry Driver Unit, this paper defines a stimulation screening method that can proactively increase production in the field. The new production criteria specify that strong stimulation candidates are wells that have produced over 17 BOPD in their history and subsequently have shown sharp production decline rates. Stimulating a well that exhibits these criteria increases the oil production rate by an average of 94%. If only 1% of the 10,000 wells in the Spraberry were acidized, an additional 1.5 MMBbl of oil and $85 million in gross revenue could be recovered.

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Section: Introductionmentioning

confidence: 99%

Using Production History to Identify Acid Stimulation Candidates in the Spraberry Trend

Coulthard¹

2007

Proceedings of SPE Annual Technical Conference and Exhibition

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“…Carbon dioxide (CO 2 ) flooding has been used as a commercial process for enhanced oil recovery (EOR) since the 1970s because significant amounts of residual oil can be recovered by CO 2 injection. − On the basis of 2002 production figures, the U.S. oil production from gas-injected EOR was estimated at 297 476 bbl/day or approximately 44.5% of the total EOR production in the U.S. However, many, if not all, gas-flooding field projects are often hampered by early CO 2 breakthrough, poor sweep efficiency, and inefficient oil recovery due to viscous fingering resulting from a low gas-phase viscosity and an unfavorable mobility ratio.…”

Section: Introductionmentioning

confidence: 99%

Improving the Foam Performance for Mobility Control and Improved Sweep Efficiency in Gas Flooding

Zhu

Ogbe

Khataniar

2004

Ind. Eng. Chem. Res.

112

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Foams are used for mobility control in enhanced oil recovery operations. However, a typical oil-field application of foam suffers from such problems as early CO 2 breakthrough, poor sweep efficiency, and inefficient oil recovery due to viscous fingering resulting from a low gas-phase viscosity and an unfavorable mobility ratio. The objective of this experimental investigation was to study the use of additives to enhance foam properties and to improve the in situ generation of foams for enhancing the gas-flood sweep efficiency. Foam generation was achieved by flowing nitrogen, surfactant, and various foam-enhancing additives through a sandpack. Some of the parameters affecting the foam performance were the polymer concentration, type of surfactants and their concentrations, aqueous-phase salinity and pH, and effect of flow rate (or shear rate). The performance of polymer-enhanced foams (PEFs) was much better than that of conventional foams. Poly(acrylamide) polymers were used as an additive. Higher foam resistance and longer foam persistence were achieved by using relatively low concentrations of polymers. The studies also showed that the foam performance was significantly improved over a broad range of polymer concentrations. A number of other investigators have shown that foams are severely affected in the presence of oil. This is especially true of lighter or less viscous oils, and the destabilizing effect is magnified with a higher salinity aqueous phase. PEFs with a low-salinity aqueous phase showed improvement in foam stability. The effective viscosities of PEFs were higher than those of conventional foams with a high-salinity aqueous phase and the presence of lighter oils. Further, PEFs reduced the negative impact of oils on foam mobility. Of the surfactants studied, R-olefin sulfonates were found to be stable with high-salinity brines as well as compatible with polymer additives. Other surfactants, including amine oxide surfactants, were also studied and showed unusually high foam resistance and stable properties.

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Learning from Water Injection Pilot in a Low Permeability Reservoir Developed with Hydraulically Fractured Horizontal Wells – ABH Field Case Study

Singh,

Agarwal,

Saurav

et al. 2023

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition

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Aishwariya Barmer Hill (ABH) is a Porcellanite oil reservoir located in the northern part of Barmer Basin in India. The formation has low permeability of ~1mD, an average porosity of 25% and has in-situ oil viscosity of ~3 cP. The ABH field has been developed with long horizontal wells with multistage hydraulic fracturing under depletion drive. The current estimated RF is 10-12% on depletion drive. To improve the RF, water flood was evaluated as the next stage of development. This paper discusses the results of water injection pilot within a complex setting with hydraulically fractured producer (observation) wells and impact of injection below and above frac pressure. Two short term injectivity tests and one long term injection pilot have been conducted in ABH field. Concepts like injection above and below frac pressure and injection in a hydraulic fractured well and a non-hydraulic fractured well were tested. The long-term injection pilot comprised of a vertical injector and two hydraulically fractured horizontal producers on it's either side. As the injection pressure was above frac pressure, data like time lapse Pressure Fall Offs (PFOs) was acquired to understand waterflood induced frac parameters. Production logging and bottom-hole pressure surveys were also conducted to understand injection profiles. Minimal injectivity was attained below frac pressure but good injectivity with sustained rate was observed above it. PTA analysis shows that fractures are induced due to water injection and time lapsed PFOs were analyzed to estimate the induced fracture parameters. Some unique signature of frac closure was also observed in PTA. Increase in water cut of one of the producer well was observed, however most of the injected water was getting imbibed into the reservoir. Role of injection water quality was also evaluated which may cause drop in injectivity and continuous frac growth. Numerical simulation was carried out to history match the observed injection performance. This indicated changes in effective permeability during injection and shut-in periods. Careful consideration of injection pressure, well design and pattern selection is critical for designing water flood in a low permeability reservoir with hydraulically fractured wells and this pilot was able to answer many questions related to it. The pilot suggested that below frac pressure injection may be required in on-trend well pattern. Poor quality injection water can cause growth of induced fracture. Response time on producer is a key consideration impacting project economics. Improving recovery from tight field development is a key area of focus and ABH pilot results will help to understand /solve some of the key considerations related to it.

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CO2 Pilot Design and Water Injection Performance in the Naturally Fractured Spraberry Trend Area, West Texas

Cited by 4 publications

References 0 publications

Using Production History to Identify Acid Stimulation Candidates in the Spraberry Trend

Using Production History to Identify Acid Stimulation Candidates in the Spraberry Trend

Improving the Foam Performance for Mobility Control and Improved Sweep Efficiency in Gas Flooding

Learning from Water Injection Pilot in a Low Permeability Reservoir Developed with Hydraulically Fractured Horizontal Wells – ABH Field Case Study

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