The Development and Qualification of a Novel Proppant System to Enhance Performance of High Rate Soft Sand Water Injection Wells With Cased Hole Sand Control Completions

2016 ◽  
Author(s):  
K. Whaley ◽  
R. Rickman ◽  
K. McClelland ◽  
T. Decker ◽  
R. Murillo ◽  
...  
Keyword(s):  
Water Injection ◽  
High Rate ◽  
Injection Wells ◽  
Sand Control

Designing Effective Sand Control Systems to Overcome Problems in Water Injection Wells (SPE93564)

2005 ◽  
Author(s):  
H. Sadrpanah ◽  
R. Allam ◽  
A. Acock ◽  
M. Norris ◽  
T. O’Rourke ◽  
...  
Keyword(s):  
Control Systems ◽  
Water Injection ◽  
Injection Wells ◽  
Sand Control

A Model for Water Injection Into Frac-Packed Wells

2010 ◽  
Vol 13 (03) ◽  
pp. 449-464 ◽  
Author(s):  
Ajay Suri ◽  
Mukul M. Sharma
Keyword(s):  
Water Injection ◽  
Horizontal Stress ◽  
Injection Rate ◽  
Injection Wells ◽  
Solids Concentration ◽  
Sand Control ◽  
Injection Water ◽  
Large Injection ◽  
Minimum Horizontal Stress ◽  
Injection Rates

Summary Frac packs are increasingly being used for sand control in injection wells in poorly consolidated reservoirs. This completion allows for large injection rates and longer injector life. Many of the large offshore developments in the Gulf of Mexico and around the world rely on these completions for waterflooding and pressure maintenance. The performance of these injectors is crucial to the economics of the project because well intervention later in the life of the field is expensive and undesirable. For the first time, we present a model for water injection in frac-packed wells. The frac pack and the formation are plugged because of the deposition of particles from the injected water, and their effective permeability to water is continuously reduced. However, as the bottomhole pressure (BHP) reaches the frac-pack widening pressure, the frac-pack width increases and a channel that accommodates additional injected particles is created. Injectivity depends on the interstitial velocity of the injected water in the frac pack, volume concentration of the solids in the injected water, injection rate, injection-water temperature, size of proppants in the frac pack, width and length of the frac pack, and the initial minimum horizontal stress. In case of frac packs with large proppant size and high injection rates, the plugging of the frac pack is found to be negligible except in the building of a filter cake at the frac-pack walls. In the case of narrow frac packs with small proppant, significant plugging is expected, which leads to sharp permeability decline of the frac pack and a rapid rise in the BHP. The long-term injectivity of a frac-packed injector depends primarily on the filtration coefficient value of the frac pack, solids concentration in the injected water, and the injection rate. Frac packs are expected to maintain higher injectivities compared to any other completions such as openhole, cased-hole, perforated, or gravel packs.

Designing Effective Sand Control Systems to Overcome Problems in Water Injection Wells

2005 ◽  
Author(s):  
Hooman Sadrpanah ◽  
Robert David Allam ◽  
Andrew Mervyn Acock ◽  
Mark Robert Norris ◽  
Tom O'Rourke ◽  
...  
Keyword(s):  
Control Systems ◽  
Water Injection ◽  
Injection Wells ◽  
Sand Control

A Novel Technique for Achieving High-Rate Water Injection at Matrix Rates in Openhole Sand-Control Completions: A Case History from Akpo Field, Nigeria

2010 ◽  
Author(s):  
Fivman Marpaung ◽  
Sebastien Bourgoin ◽  
Joseph Bagal ◽  
Damien Deffieux ◽  
Maye Beldongar ◽  
...  
Keyword(s):  
Case History ◽  
Water Injection ◽  
High Rate ◽  
Novel Technique ◽  
Sand Control

Autonomously Controlling the Conformance of Injection-Well Fluids

2021 ◽  
Vol 73 (06) ◽  
pp. 38-40
Author(s):  
Mojtaba Moradi
Keyword(s):  
Flow Control ◽  
Oil Recovery ◽  
Water Injection ◽  
Injection Well ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Control Valves ◽  
Sand Control ◽  
Control Devices ◽  
Fracture Growth

As production declines over time, the injection of fluids is required to enhance oil recovery and/or maintain the reservoir pressure. Whether applied at field startup or as a secondary recovery technique, waterflooding can boost oil recovery from less than 30% to 30–50%. The common problems associated with waterflooding include loss of injectivity, premature injector failure, and injection conformance. This can also lead to issues around insufficient voidage replacement, which can result in lower reservoir pressure and the production of fluid with a higher gas/oil ratio. In total field recovery, this ultimately means lower production and oil left untapped in the well. To remediate the issue of conformance, costly and often complex interventions and redrills were traditionally used to restore water-injection capability. Also, passive outflow-control devices have been used successfully to somewhat improve the fluid conformance from injection wells. However, they may fail in reservoirs with complex/dynamic properties including propagating/dilating fractures. Advanced Wells in Injection Wells There are a number of considerations when planning a water-injection completion, particularly around both the rock and fluid properties, as well as the credible risks that could occur, namely: - Uneven displacement of hydrocarbon - Fracture growth short-circuiting injectant-proximal wells - Fracture growth breaching caprock/basement seal - Crossflow, plugging, and solids fill Advanced completion options include deploying passive flow-control devices. For example, inflow-control devices (ICDs) are unable to react to dynamic changes in reservoir/well properties. This often requires production-logging-tool (PLT) logs, distributed temperature sensors, and/or tracers to be run and, if available, to apply the sleeve option. Alternatively, active (intelligent) completions, such as inflow-control valves, can be used, but they tend to be expensive and complicated and are limited to the number of zones. This technique also requires frequent analysis of data from the well to perform such actions. Tendeka, a global specialist in advanced completions, production solutions, and sand control, has developed FloFuse, a new and exclusively autonomous rate-limiting outflow-control device (AOCD) (Fig. 1). Using the analogy and inspiration of a home fuse box, which contains many individual fuses to control various parts of a building, the AOCD can control the excessive rate that passes through a specific section of a well, causing tripping once the threshold is reached. By almost shutting, i.e., significantly choking, the injection fluid into the fractures crossing the well, the AOCD autonomously prevents growth and excessive fluid injection into the thief/fracture zones and maintains a balanced or prescribed injection distribution. Like other flow-control valves, this device should be installed in several compartments in the injection well. Initially, devices operate as normal passive outflow control, but if the injected flow rate through the valve exceeds a designed limit, the device will automatically shut off. This allows the denied fluid to that specific compartment to be distributed among the neighboring compartments.

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