Abstract: The coalbed methane (CBM) extraction industry (an unconventional energy source) has not established guidelines for experimental evaluation of sensitivity damage for coal samples. The existing experimental process of previous researches mainly followed the industry standard for conventional oil and gas reservoirs (CIS). However, the existing evaluation method ignores certain critical differences between CBM reservoirs and conventional reservoirs, which could inevitably result in an inaccurate evaluation of sensitivity damage and, eventually, poor decisions regarding the formulation of formation damage prevention measures. In this study, we propose improved experimental guidelines for evaluating seepage sensitivity damage of CBM reservoirs by leveraging on the shortcomings of the existing methods. The proposed method was established via a theoretical analysis of the main drawbacks of the existing methods and validated through comparative experiments. The results show that the proposed evaluation technique provided reliable experimental results that can better reflect actual reservoir conditions and correctly guide the future development of CBM reservoirs. This study is pioneering the research on the optimization of experimental parameters for efficient exploration and development of CBM reservoirs.
Abstract: Acidification is a technique used in oil reservoirs
to improve annual production, reduce the skin and increase the
pressure of an oil well while eliminating the formation damage that
occurs during the drilling process, completion and, amongst others,
to create new channels allowing the easy circulation of oil around
a producing well. This is achieved by injecting an acidizing fluid
at a relatively low pressure to prevent fracturing formation. The
treatment fluid used depends on the type and nature of the reservoir
rock traversed as well as its petrophysical properties. In order to
understand the interaction mechanisms between the treatment fluids
used for the reservoir rock acidizing, several candidate wells for
stimulation were selected in the large Hassi Messaoud deposit in
southern Algeria. The stimulation of these wells is completed using
different fluids composed mainly of HCl acid with other additives
such as corrosion inhibitors, clay stabilizers and iron controllers.
These treatment fluids are injected over two phases, namely with
clean tube (7.5% HCl) and matrix aidizing with HCl (15%). The
stimulation results obtained are variable according to the type of
rock traversed and its mineralogical composition. These results show
that there has been an increase in production flow and head pressure
respectively from 1.99 m3 / h to 3.56 m3 / h and from 13 Kgf / cm2
to 20 kgf / cm2 in the sands formation having good petrophysical
properties of (porosity = 16%) and low amount of clay (Vsh = 6%).
Abstract: Permeability reduction induced by asphaltene
precipitation during gas injection is one of the serious problems in
the oil industry. This problem can lead to formation damage and
decrease the oil production rate. In this work, Malaysian light oil
sample has been used to investigate the effect CO2 injection and
Water Alternating Gas (WAG) injection on permeability reduction.
In this work, dynamic core flooding experiments were conducted to
study the effect of CO2 and WAG injection on the amount of
asphaltene precipitated. Core properties after displacement were
inspected for any permeability reduction to study the effect of
asphaltene precipitation on rock properties.
The results showed that WAG injection gave less asphaltene
precipitation and formation damage compared to CO2 injection. The
study suggested that WAG injection can be one of the important
factors of managing asphaltene precipitation.
Abstract: In this work, the precipitation of asphaltene from a Malaysian light oil reservoir was studies. A series of experiments were designed and carried out to examine the effect of CO2 injection on asphaltene precipitation. Different pressures of injections were used in Dynamic flooding experiment in order to investigate the effect of pressure versus injection pore volume of CO2. These dynamic displacement tests simulate reservoir condition. Results show that by increasing the pore volume of injected gas asphaltene precipitation will increases, also rise in injection pressure causes less precipitation. Sandstone core plug was used to represent reservoir formation during displacement test; therefore it made it possible to study the effect of present of asphaltene on formation. It is found out that the precipitated asphaltene can reduce permeability and porosity which is not favorable during oil production.