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Search Efficiency: 4.3.3 Solids
Enhanced Sand Control Operations With a Newly Designed And Manufactured Meshrite Filter
Toma, P. (Alberta Research Council) | Korpany, G. (Alberta Research Council) | Scott, K. (Alberta Research Council) | Johanson, L. (Alberta Research Council) | Russel, T. (Secure Oil Tools) | Begg, S. (Secure Oil Tools)
...m* Well dldlm" 61 61 61 61 61 Flow Duration minutes 630 1905 a53 1900 1900 Max, Flow Rate Umin 4 3 3 3 3 hh. Flow Rate per m2 Well m /dlm2 a3 61 61 61 61 Flow Duration minutes 455 1905 a53 1900 1900...
...onsolidated formations. The application reduced However, prior to 1996 the complication and of this solids control device to a wider variety of field cost of manufacturing the new f?lter maa!e it less than ...
...exceeded 20 (over-all filter density approximately 0.6 to the coarse sand fraction of the mobilized solids are 0.7 g/cm3). captured outside the filter while the fine fraction (d 40 A cubic lattice was first...
Abstract Controlling sand inflow during the production of oil and bitumen from unconsolidated formations presents an important challenge for the industry. From 1985 to 1996 a novel Meshrite (compressed metallic wool) filter has undergone a period of laboratory and field testing. Laboratory and field results have shown that the performance of this device compares favorably with that of slotted liners and screens. In testing under similar sand/fluid inflow conditions, the amount of sand produced using the new filter was reduced considerably from that using slotted liners and screens, while the pressure drop measured across the filter and skin region increased only slightly, within acceptable limits. As a consequence, oil production increased while maintenance costs were reduced. However, prior to 1996 the complication and cost of manufacturing the new filter made it less than competitive on the market. A novel manufacturing technology that substantially increases the competitiveness of the new filter was developed during 1996–1997 by Secure Oil Tools. Subsequently a methodology for testing and improving the design of the filter was developed by the Alberta Research Council (ARC). This methodology and the resulting improvements in the design of the filter, are the focus of the current paper. To measure near-well sand transport and retention mechanisms with different filter designs and formation sand, a new experimental rig was used. A filter quality test was developed to check the manufactured quality of the filter, and to observe potential degradation of the filter as a result of exposure to a corrosive environment. Using the laboratory data acquired a new partial retention model is proposed here to better explain the mechanism of partial retention with the Meshrite filter and to offer a basis for comparing Meshrite with conventional slotted liners and screens. Introduction Since 1990, a compressed metallic wool filter has been tested extensively in the laboratory and the field as a solid control device for unconsolidated formations. The application of this solids control device to a wider variety of field conditions has been limited due to:manufacturing technology problems (an imported pre-packed compressed metallic wool was locally assembled with a perforated support casing); less than competitive price; limited density of imported pre-packed compressed wool; the outside diameter of the filter-well was too large for replacing conventional applications using screens; and lack of laboratory data using the real, cylindrical filter geometry. To assess and compare the retention efficiency of different sand control completions, the ARC has developed novel laboratory testing methods, including:a computer-assisted method for rapid evaluation of sand distribution that compares satisfactorily with conventional (wet & dry) sieving, requires a relatively small sample and is performed at a considerably lower cost; a computer-assisted method for matching the particle size distribution of a formation sand with a blend of sorted sand to ensure a consistent sand pack during filter testing and comparison; and three types of flow testing apparatus
- North America > United States (0.68)
- North America > Canada > Alberta (0.48)
- Research Report > New Finding (0.46)
- Research Report > Experimental Study (0.46)
.../34 24/12 12/7 2/1 1/1 30/4 14.0 ppg SOBM 48/28 19/12 8/7 3/2 3/5 20/8 14.0 ppg OBM 67/36 24/14 9/6 4/3 3/6 31/5 17.0 ppg OBM 320/217 152/79 50/27 8/5 8/17 ND 15.3 ppg OBM 217/123 62/33 27/20 8/5 6/8 94/2...
...tene This paper was prepared for presentation at the 2007 SPE International Symposium on Oilfield solids, and to reduce the viscosity and enhance the flow Chemistry held in Houston, Texas, U.S.A., 28 Feb...
...sent in the from soybean, provides solvency required for cleaning wellbore: asphaltene and paraffin solids, OB and SOB mud performance with many attractive environmental benefits. systems, and residual pipe...utilized industrial solvent systems. its ability to dissolve or disperse these two common wellbore solids in comparison to traditional solvents such as xylene. Bio-Based Solvent Environmental Advantages I...a known weight of paraffin or asphaltene The biodegradable solvent offers several environmental and solids (0.5 grams) was added to a container with a 50 cc regulatory compliance benefits: 100% biodegradabi...
Abstract Traditional aromatic and chlorinated solvents typically utilized in oilfield applications are facing stricter governmental and environmental restrictions for their use and disposal. Concerns about flammability, acute toxicity, and environmental contamination have made their use less attractive. Furthermore, many countries in Central and South America have begun to closely monitor and regulate the manufacture, importation, and storage of typically utilized oilfield solvents such xylene and toluene due to their utilization in the manufacture of illicit drugs. In an effort to be environmentally and socially responsible, greener alternative solvents from renewable resources are continually being investigated as possible cleaning and solvent solution substitutes. This paper discusses the properties and evaluation of a 100% biodegradable non-toxic solvent blend that is derived from two renewable resources produced both in the U.S. and world. In the past, due to its price and limited availability, the solvent's use has been limited to specialized cleaning applications in the electronics industry. However, due to improved manufacturing processes, the product is more available and affordable for wider applications. The totally biodegradable solvent blend is currently being utilized heavily in paint and coatings removal, ink and graffiti removal, and electronics component cleaning. It has a Kauri Butanol (KB) solvency value of approximately 500 and is a EPA approved SNAP solvent. This paper discusses the evaluation of the biodegradable solvent blend to replace traditional solvents in stimulation packages for wellbore and formation cleaning applications. Laboratory studies were conducted to evaluate the solvent's efficiency to dissolve and remove pipe dope materials and OB/SOB mud residues and films at room temperature and 150°F. The solvent was also evaluated to determine its efficiency to dissolve and disperse paraffin and asphaltene solids, and to reduce the viscosity and enhance the flow characteristics of heavy crude oils. Introduction Crude oil present in a reservoir prior to production exist in equilibrium. As the oil is produced, changes in pH, temperature, pressure, and gas/fluid ratio can result in equilibrium upset. A by-product of this pressure and temperature drop is the precipitation of paraffin and asphaltene in the formation, flowlines, storage tanks, and surface flowlines. These deposits, as well as others such OB/SOB drilling muds and their sludges, excess residual pipe dope coatings, and thick oil sludges and deposits have a high potential to be formed both inside the wellbore and in the near well-bore formation during the life cycle of the well. Conventional acid treatments are ineffective in removing or cleaning these organic deposits, and their presence on the formation face or in the pore throats of the formation may actually prevent the acid from reaching the desired inorganic material or formation zone for the acid stimulation treatment. These organic deposits are typically dissolved and removed by organic solvents in either circulating tubular cleanouts or matrix injections. Typically these solvent treatments are conducted as solvent pre-flushes or as solvent emulsified in acid to create an acid-in-solvent dispersion to dissolve the organic deposits before an acid stimulation treatment. The external solvent phase of the dispersion disseminates or dissolves the paraffin/asphaltene, pipe dope, hydrocarbon sludge, or OB/SOB drilling mud allowing the acid internal phase to react with the inorganic component. Environmental Concerns Traditionally, most operators consider xylene and toluene to be the most effective solvents for organic deposit dispersion and removal. However, governmental regulations regarding their use, storage, transportation and volatile emission limits are increasing in the world's oil-producing areas. Concerns about flammability, toxicity, and biodegradibility have made their use less advantageous. Furthermore, their usage in the manufacture of illicit drugs has further restricted the importation, production, transportation, and storage of these materials in some Central and South American countries. As a result, regulations of these materials has greatly restricted the use of these solvents in oilfield applications.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
...1 1 5 2 2 4 3 3 6 5 6 1: PW inlet 1: PW inlet 2: Biological aerated filter 2: Aeration tank 3: Packing material...he biological loading rate (in kg COD/kg MLVSS/d, where MLVSS means mixed liquor volatile suspended solids), the hydraulic retention time (in hours), and the sludge retention time (in days). This process al...
... of biological processes in oil-production facilities. Salinity of PW, expressed as total dissolved solids (TDS) and ranging from a few mg/L to nearly 300 g/L (Baldoni-Andrey et al. 2006), is one of the cri...
... also be found in PW, as well as naturally occurring radioactive materials and inorganic production solids (Alley et al. 2011). Table 2 presents some ranges of concentration for the main metallic cations fo...
To face the growing concern regarding potentially toxic effluent discharge--such as in PW, the quantity of which is constantly increasing--biological processes could appear as a good solution because of their potentially high degradation efficiencies on a large number of molecules, their low operating costs, and their environmental friendliness (Pendashteh et al. 2012; Tong et al. 2013). Table 8 summarizes the existing studies of PW biological treatment with special attention paid to the salinity values, and Table 9 summarizes other studies of PW biological treatment with a special attention paid to hydraulic-retention-time (HRT) values. Various authors noted that the increase in salinity was associated with the decrease in COD removal. This decrease is linked to the decrease in biodegradation rate and the change in physicochemical properties of the microorganisms (Pendashteh et al. 2012) because of surfacecharge modifications that alter their filterability and flocculation (Sun et al. 2010). An increase in soluble microbial products because of enhanced bacterial lysis was also reported as the salinity increases and as biofilm detachment occurs in biofilm reactors (Sun et al. 2010).
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East > Yemen (0.92)
- (5 more...)
- Research Report > New Finding (1.00)
- Overview (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.92)
...9.9 7.7 11.4 through the sand pack. It is evident Average CO in Exit Gas, Vol. per cent 3.2 4.1 3.4 3,3 2.0 3.1 from Figs. 3 and 4 that the rate of Average 02 in Exit Gas, Vol. per ccnt 3.3 2.2 1.9 3...
...stributions of fluids nOOop, considerable hydrogen will by the combined processes of conduction and solids in combustion zones are be burned. The resulting water vapor through the solid matrix and important...and the ratio of residual with a minimum of compres liquid saturations will build up fuel to rock solids are the important ,ion costs. in cooler portions of the porous matrix variables relative to the de...
Published in Petroleum Transactions, AIME, Volume 213, 1958, pages 28–35. Abstract This paper describes the results of a laboratory investigation conducted to obtain data for an evaluation of the in situ combustion process as a method of producing crude oil from reservoirs. Air and fuel requirements, rates of advance, combustion temperatures, and coke and fluid distributions are presented. The mechanism of oil recovery by in situ combustion is discussed. Five crude oils ranging in gravity from 10.9 to 34.2 API were produced from a semiadiabatic, unconsolidated sand pack by in situ combustion. Experimental conditions were varied over a wide range in order to determine the inter-relationships of process variables. The minimum air flux requirement for self-sustained combustion was found to be less than 10 scf/hr-ft. The rate of advance of a self-sustained combustion zone was found to be nearly proportional to the air flux at the combustion front. The effects of pressure and injected air flux were studied in a series of experiments using a 21.2 API crude. A minimum air requirement was observed at an air flux of 20 scf/hr-ft. The oil saturation consumed as fuel averaged 5.5 per cent of pore volume. The effect of air pressure was found to be small for experiments having high combustion efficiencies. This study should promote a better understanding of the problems and mechanisms involved in laboratory investigations and field applications of the in situ combustion process. The data presented will be useful in the interpretation of results of field tests. When tempered with volumetric sweep efficiencies, the data can be used in making preliminary economic appraisals of the process as applied to reservoirs containing high porosity unconsolidated media. Introduction The purpose of this work was to obtain laboratory data for an evaluation of the in situ combustion process as a method of producing crude oil from reservoirs. In situ combustion basically consists of (1) injecting air into a reservoir through selected input wells to create an air sweep through the reservoir,(2) igniting the crude at the injection well, and (3) propagating the combustion front through the reservoir by continued air injection. By this means, oil is swept toward producing wells in the area. The fuel for combustion is supplied by heavy residual material (coke) which has been deposited on the sand grains during distillation and cracking of the crude oil ahead of the combustion front.
- North America > United States > Oklahoma (0.93)
- North America > United States > California (0.68)
- North America > United States > Kentucky > Furnace Field (0.99)
- North America > United States > California > Ventura Basin > Ojai Field (0.99)
- North America > United States > California > San Joaquin Basin > Midway-Sunset Field > Webster Formation (0.99)
- North America > United States > California > San Joaquin Basin > Midway-Sunset Field > Monterey Formation (0.99)
...description for System 1 Hole Number Length (cm) Height (cm) 1 3.52 0.48 2 4.4 0.48 3 4.2 0.48 4 3.3 0.48 5 2.7 0.48 6 3 0.48 7 3.1 0.48 Table 2. Holes density and dimensions for system 2 and syst...
...at emulsion stability depends on a number of factors including the heavy polar material in the oil, solids, temperature, drop size and drop size distribution, pH, and oil and brine composition. El Gamal et ...
Abstract An emulsion leak during offshore oil production operations is a real problem facing the oil industry. No work has been reported in the literature covering a technique for offshore emulsion spill cleanup. A vacuum collection system was used in this project to study the possibility of mechanical removal of emulsion spills. The system consists of sea water unit, emulsion-collecting system, vacuum unit, and air distributors. A number of operating parameters were tested such as air flow rate 0.0167×10-0.15×10 m/sec), emulsion spill thickness (0.6–3.5 mm), the height of water column in the emulsion removal system (0.40–0.85 m), and the collection unit hole size and density. The system has been tested before for the oil spill and found to be simple, fast cleaning process, efficient with minimum cost. The results of this study indicated that hole density in the collection unit has an affect on the emulsion cleanup process; and increasing the air flow rate increases the amount of emulsion removed from the system until a certain rate at which the opposed effect was observed, i.e. the studied system exhibited an optimum air flow rate for the collection of emulsion. In addition to that, the height of the water column has an effect on the cleaning process, an optimum water column height is needed to be determined for any designed emulsion removal system similar to the system used in this study. Introduction One of the major ways for oil transportation from producing to consuming counties is through sea and ocean roots and given the mount and number of vessels involved in these operations increases the risks of having different ways for oil spills. The transportation industry employs a number of techniques to mitigate effectively an oil spill at sea, namely:leave the oil alone to dispense naturally, contain the spill using different booms and clean the oil using skimmers, disperse the spill to small droplets through the use of chemical dispersants and leave the droplets to spread naturally in the sea, burn the oil spill, bio-mediate the oil spill. Many factors include the type and quantity of oil spill, spill location, weather condition during the spill time, and other factors dictates the appropriate response to an oil spill. As soon as an oil spill takes place at sea, the oil mixes with water through a series of very complicated chemical, biological and physical actions. These actions include emulsification which results in the development of an emulsion system. Emulsion is unstable system considering the thermodynamics of the system only, due to its natural tendency to separate and reduces the surface tension between the two fluids. On the other hand, the majority of oil spills emulsions are stable over a reasonable period of time. In this case the emulsion system can be classified as kinetically stable. Emulsions are classified according to their degree of kinetic stability as follows: loose emulsions: this emulsion separates in a few minutes and the separated water separates as free water in most times, medium emulsions: will separate in ten minutes or more, and tight emulsions: will separate (sometimes only partially) in a matter of hours or even days. Kodal studies ways to tackle crude oil emulsions and concluded that emulsion stability depends on a number of factors including the heavy polar material in the oil, solids, temperature, drop size and drop size distribution, pH, and oil and brine composition. El Gamal et al studied the effect of clay type and different water cuts on the emulsion stability and found that API gravity decreases with increase of clay content due to volume increase as a result of possible formation of a network of clay structure and thus trapping a large volume of oil in-between the emulsified water droplets. Although, an extensive work reported in the literature covering different techniques employed in cleaning an oil spill no work to our knowledge reported in the literature covered ways or techniques to recover an emulsion spill. In this work a vacuum technique was employed for emulsion spill cleanup. This technique has been developed and used before by Ghannam and chaalal to clean an oil spill. It consists of environmental tank, oil-collecting unit, vacuum system, and air distribution system.
- North America > United States (0.28)
- Asia > Middle East (0.28)
... section. The detailed A3 3 4 4 3 1 3 study of this screening phase was presented in a previous A4 3 3 4 2 3 2 paper (10). The results from the last step of the screening tests A5 4 4 3 2 2 3 are giv...
...t FR 98/08727. 9. Hillion, G., Dalmazzone, C., Séris, H., Huard, T., (2000). Process of cleaning of solids polluted by hydrocarbons using esters of vegetable or animal oils, French Patent FR 00/04740. 10. D...
Proposal Chemicals in decommissioning activities are not considered as an important challenge as far as all the products used are selected from the PLONOR list. Consequently, an important work has to be done to obtain safe and efficient products to facilitate cleaning operations and to limit the volumes of polluted water. The main constraint is to propose detergent formulations that are non-toxic and biodegradable. Furthermore, formulations must be compatible with cold seawater and must allow a fast separation of hydrocarbons from the aqueous phase. The objective of this paper is to present the development of a strict methodology for cleaning products selection. The innovative aspect of this methodology is firstly based on a pre-selection of safe molecules coming from a green chemistry, such as alkylpolyglycosides for instance. In a second step, formulations based on mixtures of several efficient and safe active matters are tested on different supports (glass, steel, cement...) in order to assess their detergent efficiency against several types of crude oils and weathered crude oils, the kinetics of separation of the formed emulsion, the formation of foam and the quality of the separated aqueous phase. Ecotoxicity tests on molecules are performed according to OSPARCOM guidelines (aquatic toxicity, biodegradation, and bioaccumulation). Complementary toxicity tests are also carried out on the separated water after cleaning, in order to estimate the toxicity of the aqueous phase to be discharged. The last phase of the methodology consists in a validation of formulations performances in large scale experiments performed in CEDRE (Center of Documentation, Research and Experimentations on accidental water pollutions, France), on a specific clean-up device that simulates typical operations of cleaning under pressure. The main objective is to develop green formulations for cleaning oil polluted surfaces through a rigorous methodology based on technical and environmental criteria. Introduction Decommissioning of offshore installations requires the preparation of an Environmental Impact Assessment (EIA). It has to take into account all aspects concerning technical feasibility, but also societal and environmental impacts. Of course, chemicals used for oil processing are an important and relevant environmental issue. But, chemicals in decommissioning activities are not considered as an important challenge as far as all the products used are selected from the PLONOR list (1, 2). In fact, the substances in this list are considered to Pose Little Or No Risk to the Environment. The same requirements are needed on additives such as anticorrosion ingredients, demulsifiers or other additives used during cleaning operations of the equipment before dismantling operations. The cleaning process must be well documented on the origin and location of the products, mainly production chemicals and hydrocarbons remaining in the installation. Flushing with seawater is normally applied and use of detergents is considered for cleaning improvement. Consequently, an important work has to be done to obtain safe and efficient products to facilitate cleaning operations and to limit the volumes of polluted water. Surface-washing agents that are classically used for washing hydrocarbon polluted surfaces were developed to enhance oil removal from substrates in case of accidental pollution (oil spills) (3). The most efficient products act as solvent for the heavy hydrocarbon compounds adhering on hard surfaces, but a large volume amount is required inducing problems for waste treatments. Emulsifying cleaning products that contain surfactants are also used as emulsifiers but their action favors the formation of stable emulsions that avoids hydrocarbons recovery. In this study, we propose to optimize surfactants that can be used as aqueous detergents of hydrocarbons in seawater environments in order to facilitate cleaning operations and recovery of hydrocarbons, and also to minimize the volumes of polluted waters. The main environmental objective is to replace conventional products based on prohibited chemistry such as alkyl phenol compounds or alkyl benzene sulfonates. Furthermore, products formulations must be compatible with cold seawater and must allow an easy separation of hydrocarbons from the aqueous phase.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Increased Oil and Reduced Water Production Using Cyclonic AICDs with Tracer Monitoring Applications in Peru’s Bretaña Norte Field
Acencios, L. (PetroTal Corporation, Lima, Peru) | Garcia, W. (PetroTal Corporation, Lima, Peru) | Huaranga, L. (PetroTal Corporation, Lima, Peru) | Guerrero, X. (SLB, Bogotá, Cundinamarca, Colombia) | Camelo, S. (SLB, Bogotá, Cundinamarca, Colombia) | Gurses, S. (SLB, Houston, Texas, United States) | Williams, B. (RESMAN, Houston, Texas, United States)
... Compartment 20 19 18 17 16 15 14 13 12 11 10 9 8 7 6 5 4 3 2 1 % Inflow 4 4 4 4 4 4 4 7 7 11 3 4 4 3 3 3 3 3 5 18 Heel Toe...
...ud that was used to drill this section was replaced with a 9.2-ppg formate-based mud to guarantee a solids-free completion fluid. Before the screens were run in the hole, a surface backflow test and a plugg...
Abstract This paper presents the successful application of cyclonic autonomous inflow control devices (AICDs) for water management and the use of chemical tracers for monitoring and controlling the productivity of the different units to increase oil recovery in Peru’s Bretaña Norte Field by shuting down or choking units producing monstly water. The reservoir comprises an unconsolidated sandstone formation with an active aquifer and contains heavy oil with 23-cp viscosity downhole. The field’s location presents environmental and operational challenges, and the development plan seeks to use the latest technology to achieve production goals while minimizing the environmental impact. AICDs were identified as a technology solution to improve oil recovery. Unique chemical tracers were embedded in the sand screens to measure the oil and water production from each compartment without the need for well intervention. An integrated approach and technology workflow were used for a candidate well and included well placement using logging while drilling, predesign of AICD completions using advanced well modeling, tracer installation in the standard sand screen, and post-installation analysis of tracer samples to determine the flow contributions from each compartment and AICD performance along the wellbore. An optimized lower-completion strategy was essential to the planning and execution of the candidate well, which had challenging environmental constraints. The completion design was adjusted to obtain the estimated optimal inflow by identifying the number of compartments and AICDs required in each one along the 1,000-m-long horizontal well section. Incorporating the tracers as part of the permanent installation eliminated the potential need for an intervention and enabled the quantification of each compartment’s contribution during the cleanup and production phases. Tracer samples indicated a good cleanup, and the initial well performance was observed to have no water production. A few months after the cleanup was performed, water breakthrough occurred, and tracer analysis was used to identify the first compartments in which it occurred, helping the operator identify vertical heterogeneities at a structural level. Following 1 year of production and monitoring, oil recovery increased by 100% for this well compared to that of offset wells (from 15 to approximately 30%). Water production decreased by almost 2 million bbl per year, which represents a 50% decrease in the energy required to produce and treat water. The successful application of cyclonic AICDs with chemical tracers for monitoring in Bretaña Norte Field demonstrates that the oil production and recovery factor of heavy-oil fields with a strong waterdrive can be improved. This case study, which provides the results of 1 year of production, can serve as guidance for similar fields throughout Latin America. The resulting energy savings represent an important milestone in terms of reducing carbon dioxide (CO2) emissions and overcoming environmental challenges.
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.74)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.54)
- Geology > Sedimentary Geology > Depositional Environment (0.46)
- South America > Peru > Marañón Basin > Vivian Formation (0.99)
- North America > United States > Wyoming > Pedro Field (0.93)
- Asia > Middle East > Israel > Central District > Southern Levant Basin > David Field (0.93)
...7 2.9 2.4 2.1 1.8 1.6 1.5 1.3 1.0 0.9 0.6 0.4 0.3 0.1 0.1 0.0 0.0 -0.004 17.4 11.6 8.7 7.0 5.8 5.0 4.3 3.9 3.5 3.2 2.5 2.0 1.4 1.0 0.6 0.3 0.2 0.1 0.0 -0.005 34.0 22.7 17.0 13.6 11.3 9.7 8.5 7.6 6.8 6.2 ...
...9 71.9 42.1 24.4 13.9 6.0 2.0 3.75 -0.004 52.2 34.8 26,.1 20.9 17.4 14.9 13.1 11.6 10.4 9.5 7.5 6,1 4.3 3.1 1.8 1.0 0.6 0.3 0.1 -0.005 102.0 68.0 51,.0 40.8 34.0 29.1 25.5 22.7 20.4 18.5 14.6 12.0 8.5 6.0 ...
...tube adheres to internal pump surfhces. The problem that pump is necessary for efficient passage of solids occurs in these conditions with standardpumps is that through the plungerhamels interfhce. the scal...
Abstract Sand and other fluid entrained particulates can cause substantial operational problems for rod pumped producing wells. These problems take the form of down- hole pump wear, plunger sticking, and/or catastrophic breakage of pump components. A six year study of 600+ pump investigations shows that problems with particulates account for a substantial number of the total barrel and plunger failures. Many of these failures could have been avoided through the proper application of API and special pump designs as well as certain choices of pump variables. These pump variables and designs will be addressed along with operating parameters. How hard is sand? How large is it? Should plunger and barrel choices take these variables into account? Also, metal plungers must "slip" fluid for proper lubrication. Too much slippage leads to pump inefficiencies. However, down-hole pump efficiencies based on slippage need to be balanced against pump longevity due to proper selection for particulate production. Some time-proven rules of thumb can be applied to make these choices, and an included chart will make plunger slippage calculations simple and straightforward. Scale which sticks to pump surfaces dictates the choice of a different style down-hole pump. A straight-forward modification of an RH style API pump has proved successful in these conditions. Fluid and particulate production with and without attendant gas production requires a different approach to down-hole pump selection. Several successful older pump designs as well as some recently proven new designs will be described. A test program has been completed and actual applications have shown that an API Tubing Pump derivative can pump large volumes of particulate laden fluid without characteristic sticking of the plunger. Introduction A study was conducted of pumps with relatively short run times during the years from 1989 through 1994. These were analyzed with respect to pump barrels or plungers that had problems due to produced particulates. A significant number of the barrels and plungers developed problems due to particulate induced wear or sticking (Figs. 1 and 2). Costs of new rod pumps and pump repairs are typically closely monitored, perhaps at the expense of overall well production profitability. A different costing focus may be applicable, and appropriate record keeping is necessary for accurate cost analysis. New record keeping methods are available which pinpoint areas for improvement. Variables For Rod Pumping Several general pumping choices for the down-hole pump must be logically made for optimum functioning and efficient longevity. These apply to any pump and include; pump metallurgy, plunger minus fit choice, and slippage design for lubrication of the plunger and barrel interface. Pump Metallurgy. pump wear is the primary consideration when particulates are produced along with the production fluid. Sand grains can be as hard as hardened steel (Table 1), causing contact wear and erosion of pump surfaces. The two surfaces that receive the most wear are the barrel and plunger surfaces. These two parts of the pump form the moving surfaces of the pump that are subject to sliding wear during each stroke of the pump. During a typical 24 hour pumping day at 10 strokes per minute, a plunger and barrel will see over 14,000 cycles of up and down motion contributing to plunger and barrel wear. For a 100" long down-hole stroke length, the total distance of sliding wear is about 45 miles per day. Barrel Metallurgy. The oldest and most popular choice of inside wearing surfaces for pump barrels is hard chrome plating. The hardness is Rc67 minimum, and the chrome plating seldom wears out. Its weakness is due to its intolerance of hydrochloric acid, which is commonly used for remedial acid treatment of oil wells, and other corrosive fluids which attack the chrome plating bond line. Hydrochloric acid will dissolve chrome plating. Any down-hole formation fluid with a Ph below 7, or other corrosive down-hole fluids will eventually cause chrome plating to flake off, through weakening of the chrome to substrate bond line. This invariably leads to further damage to the barrel and plunger by the hard chrome particles which have flaked off of the barrel. This weakness is one of the reasons that chrome plating seldom wears out. It is more likely that it will eventually flake off in some area before it wears out, even if the barrel has given a satisfactory run time. Therefore, a chrome plated barrel has one likely early failure mode; flaking off of the plating, and two possible normal "used up" modes; wearing away or flaking off of the chrome plating. A significant number of the barrels represented in the failure study had problems with chrome flaking. None had problems with worn chrome. A nickel carbide coating is available for the inside and outside surfaces of pump barrels. It provides a hard wearing inside surface and an outside corrosion barrier. P. 105
- North America > United States > New Mexico > San Juan Basin (0.99)
- North America > United States > Colorado > San Juan Basin (0.99)
- North America > United States > Arizona > San Juan Basin (0.99)