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Results
Abstract Multi point hydraulic fracturing in unconventional hydrocarbon bearing shale reservoirs has been proven to greatly enhance production economics. A major component of these multi point fracturing systems consist of tripping balls used to actuate fracturing sleeves. The sleeves are used to focus fracturing initiation and placement. The tripping balls may experience pressures approaching 10,000psi. Recent technology has allowed as many as 40 individual fracture points. Once the formation has been fractured the tripping balls may hinder production. One potential problem is related to the tripping balls becoming stuck on the fracturing seats. Tripping balls remaining in the lateral can create a choking effect and also lead to problems if wellbore re-entry is required. These risks to production can lead to significant increased costs and potentially lost production. A new high strength corrodible material has been developed and used for tripping balls to alleviate these potential problems in these unconventional reservoirs. This material has yielded a truly intervention-less means of flow assurance. The mechanical properties and corrosion rates of these newly engineered materials have been investigated to determine the downhole performance. The characterization results of these materials will be discussed and compared to other materials currently used for tripping balls. The testing included investigation of the corrosion rates of these materials in brines and acids at various temperatures and pressures. Materials were also functionally tested on multiple ball seat configurations used in the multi-zone fracturing systems.
Abstract Numerical simulation has been used, as common practice, to estimate the CO2 storage capacity in depleted reservoirs. However, this method is time consuming, expensive, and requires detailed input data. This investigation proposes an analytical method to estimate the ultimate CO2 storage in depleted oil and gas reservoirs by implementing a volume-constrained thermodynamic equation of state (EOS) given average reservoir pressure and fluid composition. This method was implemented in an algorithm which allows fast and accurate estimations of final storage, which can be used to select target storage reservoirs and design the injection scheme and surface facilities. Impurities such as nitrogen and carbon monoxide, usually contained in power plant flue gases, are considered in the injection stream and can be handled correctly in the proposed algorithm by using their thermodynamic properties in the EOS. Results from analytical method presented excellent agreement with those from reservoir simulation. Ultimate CO2 storage capacity was predicted with an average difference of 1.26 wt% between analytical and numerical methods; average oil, gas, and water saturations were also matched. Additionally, the analytical algorithm performed several orders of magnitude faster than numerical simulation, with an average of 5 seconds per run.
- North America > United States (1.00)
- Europe (0.68)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.95)
- South America > Colombia > Mirador Formation (0.99)
- South America > Colombia > Casanare Department > Llanos Basin > Cupiagua Field (0.99)