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Organic deposit including asphaltene and paraffin may damage the near wellbore area and obstruct production tubings resulting in partial or total loss of well productivity. Most of asphaltene deposits are associated with paraffin. This paper presents a first successful field application of a lab proven/optimized chemical solvent to remove organic deposits from a dead oil well in a sandstone reservoir. A vertical gravel-packed oil producer well was dead due to deposition of organic material in 3 ½" production tubing forming obstruction to flow. The deposition is expected to take place due to long shut-in time as experienced in this well with high GOR. A bailer samples was obtained from this well. Analysis of the obstructing material indicated that they were mainly asphaltene associated with paraffin. Solubility of obtained organic deposits in several solvents was evaluated at reservoir temperature (188°F) and monitored as a function of soaking time. Several criteria were considered in selecting of the optimal solvent formulation, among which were safety and solvency power. The selected formulation incorporates asphaltene dissolver solvent and paraffin dissolver solvent in addition to surfactant. Application of the optimal solvent formulation, that exhibited the maximum solvency power in a minimum soaking time, was very effective in restoring well productivity while minimizing operational cost. A total of 12 feet of obstructing organic deposits were removed from the production tubing using coiled tubing in a multi-stage treatment. Following, the solvent was squeezed into the formation across the screens to maximize cleaning efficiency at the source. The sustainable oil production rate obtained and asphaltene content in flow back samples indicated that the treatment was very successful. To prevent further asphaltene/paraffin precipitation during shut-in time, asphaltene/paraffin inhibitor is recommended. A detail of asphaltene/paraffin formation mechanism, lab evaluation and field application results will be addressed.
Organic deposit including asphaltene and paraffin may damage the near wellbore area and obstruct production tubings resulting in partial or total loss of well productivity. Most of asphaltene deposits are associated with paraffin. This paper presents a first successful field application of a lab proven/optimized chemical solvent to remove organic deposits from a dead oil well in a sandstone reservoir. A vertical gravel-packed oil producer well was dead due to deposition of organic material in 3 ½" production tubing forming obstruction to flow. The deposition is expected to take place due to long shut-in time as experienced in this well with high GOR. A bailer samples was obtained from this well. Analysis of the obstructing material indicated that they were mainly asphaltene associated with paraffin. Solubility of obtained organic deposits in several solvents was evaluated at reservoir temperature (188°F) and monitored as a function of soaking time. Several criteria were considered in selecting of the optimal solvent formulation, among which were safety and solvency power. The selected formulation incorporates asphaltene dissolver solvent and paraffin dissolver solvent in addition to surfactant. Application of the optimal solvent formulation, that exhibited the maximum solvency power in a minimum soaking time, was very effective in restoring well productivity while minimizing operational cost. A total of 12 feet of obstructing organic deposits were removed from the production tubing using coiled tubing in a multi-stage treatment. Following, the solvent was squeezed into the formation across the screens to maximize cleaning efficiency at the source. The sustainable oil production rate obtained and asphaltene content in flow back samples indicated that the treatment was very successful. To prevent further asphaltene/paraffin precipitation during shut-in time, asphaltene/paraffin inhibitor is recommended. A detail of asphaltene/paraffin formation mechanism, lab evaluation and field application results will be addressed.
An organic deposit cleanout job was successfully performed on a horizontal openhole Arab-D reservoir oil well and a high oil rate was restored from the dead well. The well was treated with a proprietary chemical solvent using bullheading and coiled tubing (CT) jetting technique to have maximum coverage of the wellbore from the tubing to long open hole horizontal sections. The treatment performed for this job representedthe first application of this chemical in a carbonate field of North Ghawar. A few wells in this area, lying within the boundary of a gas cap, have experienced asphaltene/paraffin problems that resulted in productivity decline and wellbore inaccessibility. A high gas-oil ratio (GOR) has been thought to be the main reason for asphaltene/paraffin precipitation inside the wellbore and near the formation. Organic depositswere observed to have accumulated in the wellhead and shallow tubing depth. This well was drilled in 2007 on the periphery of the south gas cap of the field and died after being on production for three years at a relative low watercut. The well was reported with a high GOR and water cut around 2% to 3% before dying. Analysis of a downhole sample confirmed 100% hydrocarbon with 81% asphaltic presence. The asphaltene/paraffin deposition was identified as the main reason for the death of this well. Chemical/solvent treatment using a CT jetting/pulsating mechanism was employed to have a maximum benefit. The solvent was proven in the lab to be very effective in dissolving asphaltene/paraffin and had a higher flash point. The job was performed in two stages. In the first stage, about one tubing volume of the solvent was bullheaded and left for soaking for 24 hours. In the second stage, the solvent was placed using 2" CT in the open hole section. This paper describes in detail the nature of the asphaltene problem in this area, the formation mechanism, treatment selection, design and execution, and future prevention approach to avoid recurrence.
Several wells in a carbonate reservoir have experienced significant reduction in their oil productivity. Bailer samples collected from these wells showed that they were damaged with organic/inorganic deposition. Analysis of the collected material showed that the organic deposits consisted of asphaltene and associated paraffins while the inorganic deposits were mainly calcite with ankerite, anhydrite and small amounts of quartz and halite. The formation of calcium carbonate scale is anticipated to occur due to CO2 degassing during production. In addition, these wells produce commingled oil from two carbonate reservoirs which allow their formation waters to mix together; therefore, scaling tendency prediction showed a positive saturation index for calcium carbonate. The sulfate scale in the form of anhydrite is anticipated to be formed due to mixing of high sulfate source (seawater), used to maintain reservoir pressure, with a calcium rich source (formation water). The colloidal instability index from SARA analysis indicated that the reservoir oil in this field has a moderate instability to potentially precipitate asphaltenes. Additionally, the interaction of low pH scale inhibitor with the formation oil and presence of charged particles such as calcite will destabilize asphaltenes in oil. Two techniques were examined toward dissolving the organic/inorganic deposition including a two-stage and a single-stage method. The two-stage method involves the use of solvent preflush to remove the organic coating material from the whole deposits followed with the use of HCl acid to remove the remaining inorganic deposits. An emulsified HCl acid/solvent is used in the single stage method to remove the whole deposits. The paper discusses different analytical techniques used to identify the nature of the damaging material, mechanism of organic/inorganic deposition, and the optimization of dissolver/solvent systems to remove formation damage and restore productivity of damaged wells. It also assesses and optimizes the current used scale inhibitor squeeze (SIS) treatment program.
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