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SPE Members Abstract This paper compares sand control methods used in vertical oil and gas wells with a relatively new method used in the first horizontal well drilled in Bolivia. Even though production from the horizontal well has not exceeded that from nearby vertical wells by the expected margin, initial results are encouraging. Production from a zone previously considered low yield has been at previously considered low yield has been at an acceptable level and through a larger choke than normally used in the area. The sand control method utilized may be extended to vertical wells. Introduction Sand production in oil and gas wells is one of the greatest problems facing the National Oil Company, Yacimientos Petroliferos Fiscales Bolivianos, (YPFB) in Bolivia. The majority of wells produce from sandstone formations laid down in a continental environment. In this type of formation, sand grains are unconsolidated, or partially bonded to a clay medium similar to natural cement. Fluids introduced to the formation at the perforation stage, high flow perforation stage, high flow velocities and perforation stage, high flow velocities and the presence of formation water cause the wells to produce sand, and consequently, production levels in most of the fields are production levels in most of the fields are severely affected or restricted. Practical experience in Bolivia has shown Practical experience in Bolivia has shown that without doubt, the mechanical (gravel packing) method of sand control has been packing) method of sand control has been the most successful in vertical wells. Nevertheless, use of perforated pre-packed filter screens as a liner in the first horizontal well has proved to be an effective and economical method to control sand production and could also be used in vertical wells. Since the majority of Bolivia's reserves occur in unconsolidated formations, it is imperative to determine the best sand control method to optimize hydrocarbon production, extend the productive life of production, extend the productive life of the wells, and hence, substantially improve the profitability of development projects and operation of the fields. P. 141
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > South America Government > Bolivia Government (0.54)
- South America > Bolivia > Santa Cruz Department > Vuelta Grande Block > Vuelta Grande Field > Petaca Formation (0.99)
- South America > Bolivia > Santa Cruz Department > Vuelta Grande Block > Vuelta Grande Field > Cangapi Formation (0.99)
- South America > Bolivia > Chuquisaca Department > Vuelta Grande Block > Vuelta Grande Field > Petaca Formation (0.99)
- South America > Bolivia > Chuquisaca Department > Vuelta Grande Block > Vuelta Grande Field > Cangapi Formation (0.99)
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Sand Control (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
Mechanical Fluid-Loss Control Systems Used During Sand Control Operations
Restarick, H.L. (Otis Engineering Corp.)
SPE Member Abstract The most common problem during the sand control operation is fluid loss. It is an inherent problem encountered worldwide, due to the high permeability of sandstone reservoirs which allows easy fluid flow into the formation matrix. Many wells which are candidates for sand control produce from marginal reservoirs and have insufficient bottomhole pressures to support a column of fluid in the wellbore. Still other wells with high pressure zones require high density completion fluids in order to balance the reservoir pressure during the gravel pack operation. In either case the positive pressure leads to fluid being lost to the pressure leads to fluid being lost to the reservoir. The result presents several potential problems: (1) formation damage potential problems:(1)formation damage caused by swelling of clay minerals within the formation, (2)formation damage due to particle invasion into the formation (3)particle invasion into the formation (3)formation damage due to dissolution of matrix cementation promoting migration of fines within the formation (4)flow channel blockage by precipitates caused by ionic interactions between well servicing fluids and formation fluids (5)interactions between well servicing fluids and formation fluids causing emulsion blocks, water block,, or changes in wettability of a producing sand and (6)flow channel producing sand and (6)flow channel blockage due to viscous fluids creating a barrier in the near wellbore region. The need for mechanical fluid loss control systems in these situations is, therefore, obvious. Introduction During many sand control operations the standard procedure is to acidize the formation prior to gravel packing, thus increasing the near wellbore permeability. Then it is recommended that the acid treatment be followed immediately with the gravel pack treatment until a sandout occurs. After gravel packing, the wellbore is frequently in a lost circulation condition. This requires either keeping the hole full, resulting in large volumes of fluid lost to the formation, or unknowingly spotting an inappropriate fluid loss pill. Both options can result in formation damage and excessive costs. P. 21
- Geology > Mineral (0.54)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.54)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Completion > Sand Control > Gravel pack design & evaluation (1.00)
- Well Completion > Completion Installation and Operations > Fluid loss control (1.00)
Use of Reeled Tubing in Gas Lift Completion Systems
Bortolin, L. (Maraven S.A.) | Johnson, K.J. (Otis Engineering Corp.) | Bechtold, H.D. (Otis Engineering Corp.)
SPE Members Abstract This paper will demonstrate the use of reeled (coiled) tubing applied to gas lift technology and will add another method to the growing list of service and production capabilities now facilitated by reeled tubing. By using reeled tubing to install conventional gas lift valves, production enhancement of many wells is possible without workovers or change of existing tubulars. This paper will discuss the design parameters, components and actual field parameters, components and actual field results of using reeled tubing to install gas lift valves. Introduction MARAVEN, one of the three sister companies of the Venezuelan national oil company PDVSA, is responsible for more than 2000 producing wells in the Lake Maracaibo area. Of these, 20% are producing naturally from formations that will eventually require some form of artificial lift. In order to work these wells over, a number of workover rigs are required. Logistics dictate that candidate wells may need to wait several months before a workover rig becomes available and remedial work can be performed. During this period wells are normally shut in. One simple and efficient means to produce these wells, during the waiting period, is to equip them with a "remedial" reeled tubing gas lift system installed inside the existing well tubulars. The reeled tubing is equipped with gas lift valves. An annular gas lift design was selected to maximize fluid production. INITIAL COMPLETION In 1989, MARAVEN decided to explore methods of placing wells on gas lift without having to work the wells over. Due to an active workover program, availability of workover rigs, and the Venezuelan government's desire to increase the country's oil production, it was decided to evaluate the production, it was decided to evaluate the possibility of producing the oil wells with possibility of producing the oil wells with annular flow in a "macaroni" type completion. P. 467
- North America > United States > Alabama (0.33)
- South America > Venezuela > Zulia > Maracaibo (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > South America Government > Venezuela Government (0.54)