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Handil field is a mature oilfield located in East Kalimantan Indonesia, operated by TOTAL E&P Indonesie (TEPI). By 2012, there were several wells completed with Gravel Pack completions that were producing sand during production phase. This condition created a hydrocarbon production limitation around 3700 bopd from three oil wells. TEPI were looking...
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... meant better quality main pill mixes were achieved. Figures 9 and 10 show this with much less floc seen in the main pill volumes. The coiled tubing was run in hole to approximately 20m above the SSD's targeted zone. ...
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... the treatment fluid was placed into targeted formation, the treatment was left to cure for a minimum of 48 hours. Fig.11 shows an example of pressure behaviour during the sand consolidation treatment. ...
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... injecting the placement volume of diesel into Zone 4 of the second well to be treated it was noted that the circulating and wellhead pressure started to increase. This is shown in Fig 12. As a result of the pressure increase, the decision was taken to stop pumping, to avoid concern over reservoir fracturing. This meant that not all of the placement diesel was deployed. ...
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... the time of writing, single zone assessment observation is still performed prior to a planned softSCON retreatment. Production before and after softSCON and production history are summarized in Table 2 and Figure 13. It should be remembered that for all these treatments the key concern was to prevent sand production and at the treatment rate of 8% some production restriction was accepted. ...
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... the clean up results after the softSCON retreatment, these zones show good potential and no sand production. Production before and after both sets of treatment and the production history are summarized in Tables 3a and 3b and Figure 14. Table 3a-Well 2 production before and after softSCON Table 3b-Well 2 production before and after further softSCON treatment Well 3 This Handil infill well was drilled and completed with gravel packs in May 2012. ...
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Citations
... One important note in using organosilanes is that they do not reduce permeability because they react with sand on the surface and do not form a thick polymer, which could reduce permeability. 162 Gels. Gels are composed of one or more polymer solutions with one or more cross-linkers, which cause the polymer chains to cross-link together. ...
This review aims to bring together the studies on petroleum reservoirs' sand production control in a comprehensive guide for the researcher to compare various methods for the chemical consolidation of sand. Sand production can be considered one of the major challenges in the petroleum production industry, causing severe operational issues. This study introduces various methods to control and prevent sand production in petroleum wells and evaluates their advantages and performance in tabular form. The use of chemical procedures is considered to be more efficient in counteracting the production and migration of sand. Various chemicals and polymers have been proposed for this purpose. These chemicals should increase the consolidation of the formation rock while not reducing its permeability. The complexity and simplicity of the substances will be the two main factors. Novelties are generally tied with complex chemical structures. Conversely, simplicity makes them affordable, which is essential for industrialization. Success is obtained when the two are combined. This Review is expected to allow individual experts to compare various methods and be a handbook guiding them in the pursuit of finding the appropriate method of sand control for each reservoir.
... -Sand consolidation applications, using various products, has been started in 2008(Chaloupka et al. 2010, Chaloupka et al. 2012, Fuller et al. 2011, Mahardhini et al. 2015). -Coiled tubing unit to convey sand consolidation is available daily in TEPI. ...
Tunu field, which is located in Mahakam area, consists of sandstone reservoir. Due to the maturity of the field, producing layer has moved from the deep zone, which has consolidated sand, into shallow zone, which has unconsolidated sand. Hydrocarbon production from shallow zone is unmanageable without having primary sand control downhole.
Here, we present a new type of sand consolidation composite (or hybrid) low-viscous binding material, based on combination of both inorganic and organic components. After describing the properties of this material, like low viscosity and strong adhesion to sand surface, we introduce the models used in the laboratory to stay as close as possible to the injection parameters on the field. We present the results of consolidation and regained permeabilities obtained in the laboratory with this binder on several substrates (loose sand and sand stone cores) with various porosities. The formulation was tested with success on samples ranging from several darcys down to 80 millidarcys. It is also noteworthy that samples display strong consolidation after extensive brine-based overflush.
Then, this paper discusses the results obtained during eight field trials divided into three successive campaigns. The volume of water-based overflush was identified as the main parameter to find the right balance between consolidation strength without sand production and expected productivity. We achieved improvement of the formulation as well as learning curve from each campaign. After first campaign with 6 pore volumes overflush, three wells out of five produced sand free. During second campaign (1.5 pore volume overflush), two wells were treated and able to produce sand free with average gas rate 1 MMscfd (million standard cubic feet per day), after productivity impairment was solved. The trial on one well in a third campaign with 3 pore volumes overflush was successful, with the well producing sand free with average gas rate 0.8 MMscfd.
Unconsolidated sandstone reservoirs are most susceptible to sand production that leads to a dramatic oil production decline. In this study, the poly(4-vinyl pyridine) (P4VP) incorporated with self-aggregating behavior was proposed for sand migration control. The P4VP could aggregate sand grains spontaneously through π-π stacking interactions to withstand the drag forces sufficiently. The influential factors on the self-aggregating behavior of the P4VP were evaluated by adhesion force test. The adsorption as well as desorption behavior of P4VP on sand grains was characterized by scanning electron microscopy and adhesion force test at different pH conditions. The result indicated that the pH altered the forms of surface silanol groups on sand grains, which in turn affected the adsorption process of P4VP. The spontaneous dimerization of P4VP molecules resulting from the π-π stacking interaction was demonstrated by reduced density gradient analysis, which contributed to the self-aggregating behavior and the thermally reversible characteristic of the P4VP. Dynamic sand stabilization test revealed that the P4VP showed wide pH and temperature ranges of application. The production of sands can be mitigated effectively from 20 to 130 °C within the pH range of 4–8.
Loosely consolidated or unconsolidated reservoir is susceptible to sand migration that results in rapid production decline and short-lived stimulation enhancement. In this study, water-soluble organosilane used for sand migration control was proposed by considering in-situ hydrolysis and polycondensation effects. A variety of organosilanes were screened by evaluating their hydrolysis and polycondensation rate. The suitable structure of organosilane for sand consolidation was determined. Based on the selected organosilane FX, various factors influencing hydrolysis and condensation rates were studied to determine the usage of organosilane. The result indicates that the rate of hydrolysis and polycondensation dominates the consolidation performance of organosilane by changing the amount of active Si-OH reacting with sand surface. HCl was used to control hydrolysis and polycondensation rate of the organosilane with appropriate formation temperature, operation and shut-in time. The various process control parameters were optimized with the organosilane concentration of 3%–5%, the catalytic HCl concentration of 1%–3%, and formation temperature lower than 100 °C. Static and dynamic sand stabilization experiment showed that the organosilane had a high compressive strength, little loss of permeability, long-term stability against typical formation fluids, and wide compatibilities with various types of acidizing slug. Micro-experiment confirmed the in-situ generation of a hydrophobic film on the touchpoint of sand surface connecting migrated sand with matrix.
