Oil producers sometimes perform unexpectedly below expectations. Low performance could be caused by many reasons. Formation damage inside the near wellbore region, liquid load-up, and high back pressure imposed by the production system are just some listed among the many reasons. To revive or to boost the production of under-performing wells, especially impacted by liquid load or by high back pressure, a surface jet pump provides a quick and economical way as it consumes no external energy such as electricity and contains no moving parts. The surface jet pump utilizes the pressurized fluids from a good producer to generate a suction power. The suction power created can be then used to reduce the back-pressure imposed on a weak producer sitting beside the good producer. The performance of this weak producer is therefore improved. Presented and discussed in this paper is the brief description of working principle of a surface jet pump, factors affecting its performance, candidate well selection for the application, and a case study for one trial test of a surface jet pump in Safaniya field. Intensive well rates data along with wellhead pressure reduction over 60 days under different testing scenarios were collected, analyzed and presented to showcase the success of its application in one location of Safaniya field. The trial test was successfully completed with positive results showing the feasibility of production boosting capacity achieved by a surface jet pump through both real production increase and reduction of back pressure imposed on the weak producers. To streamline the field implementation of the surface jet pump, and to meet the production increase expectation, some factors highlighted in the paper, which have a big impact on its outcome, must be carefully examined when choosing a candidate well for the application. Failure to consider the importance of those factors would result in no production gain at all.

To a great extent, experiment selection of temporary plugging particles(TPP) in the temporary plugging techniques (TPT) is blind at present. Based on the investigation of particle migration, deposition and plugging mechanism in the porous media, network model, the inter-connected pore and throat network on the basis of reservoir pore structure, is applied to the optimization of TPP in the TPT. It is shown that the result of simulation has a good agreement with that of core fiooding experiment and can be used to guide the study of core flooding experiments. The main advantages of this method are:the model can be repeatedly used many times and can be used in the simulations of various purposes and aspects;the results are highly comparable by the simulation while much less by the core flooding experiments. Introduction It's well known that formation damage existing extensively in each phase of field operations is a difficult problem in the petroleum industry, and can not only damage oil and gas resources and considerably reduce the productivity of hydrocarbon reservoirs, but also even kill hydrocarbon reservoirs, and therefore cause a very great waste of manpower, material and financial resources. During the past several decades, beginning with our original consciousness of formation damage problem, unremitting efforts and a great number of researches have been made from the understanding of formation damage mechanism in the past to the controlling and preventing of formation damage by using various methods at present.

Well testing is one of the most vital data obtained, which provides numerous information that is related to the well's performance. It is also important to acquire an accurate rate test for reliable allocation and production planning. This paper's objective is to analyze and compare the accuracy of two different types of multiphase flowmeter (MPFM) against a conventional portable test separator. These two types of MPFMs are from two different vendors and each has its own mechanism. A portable testing campaign was initiated with the intention of comparing the MPFMs’ phase rates against those of the separator. The portable testing unit (PTU) was connected downstream to the MPFMs, which were visited pre-campaign by their respective vendors and the required calibration was conducted. A total of 41 wells from various reservoirs and production conditions was evaluated with multirate tests. Overall, the results showed a considerable difference between the phase rates of the traditional test separator and those of the MPFMs regardless of the type where both MPFMs did not meet the minimum requirement of having an acceptable error percentage and only nearly 50% of the tests were within an error range of 10%. One MPFM marginally outperformed the accuracy of the other one. Two problematic regions with high discrepancy between the two metering types were identified either under low-liquid rates or high gas-volume fraction (GVF). Some identified causes will be discussed, which can be of high use by operators who are willing to conduct such comparisons.

To a great extent, experiment selection of temporary plugging partic1es(TPP) in the temporary plugging techniques (TPT) is blind at present. Based on the investigation of particle migration, deposition and plugging mechanism in the porous media, network model, the inter-connected pore and throat network on the basis of reservoir pore structure, is applied to the optimization of TPP in the TPT. It is shown that the result of simulation has a g(x)d agreement with that of core flooding experiment and can be used to guide the study of core fl{x)Jing experiments. The main advantages of this method arc: 1. the model can be repeatedly used many times and can be used in the simulations of various purposes and aspects; 2. the results are highly comparable by the simulation while much less by the core flooding experiments_

Accurate and timely well rate tests ensure prompt operating decisions and effective reservoir management, especially for shut-off of any unwanted fluid. A conventional well testing system typically employing a two-phase separator and single-phase flow meters has widely gained industrial acceptance in highly productive oil fields. Because of full range water cut capability, immunity to fluid compositional change and flow disturbances, no wearing parts and high measurement accuracy, a Coriolis flow meter as a single-phase flow meter gained popular installation in such conventional well testing systems over the last few decades. Positive results had been produced from such Coriolis flow meters in one of Saudi Aramco's operating oil fields over the last decade. Consequently, as a result of invasion of gas cap gas, the existing testing facility could not provide very reliable well testing results recently in this oil field. Testing deficiency significantly impacted the reservoir management decisions for effective shut off of excessive gas production in some oil producers. Intensive well rate testing campaigns using different technologies, including multiphase flow meters (MPFMs) were conducted. The analysis of testing results revealed that some factors greatly impact the measurement accuracy from a Coriolis flow meter, which primarily led to the testing deficiency in this field. Discussed and analyzed in this paper is how the quality of the testing data is affected by the influential variables, testing facility configuration, and operating process. The root causes of testing deficiency were identified and specific solutions to solve those issues proposed. Innovative flow calculation formulae are developed to rectify the reported testing data and verified by other source testing data. As a result, testing efficiency was improved by 30%~60% by the existing testing facilities in this field. Also described in this paper are lessons learned, which will enrich the technical knowledge base. As a result of this work, an approximate $3 million investment could be avoided to replace the existing 30 plus testing facilities with new MPFMs. Introduction Well testing always provides critical decision making information at every stage of an oil field's development life. At the early stage during the oil exploration, well testing helps the engineers to confirm whether the underground hydrocarbon reserve can be economically tapped using whatever technology is available in the market and to prove the estimated reserves. During the normal development of a field or a reservoir, well testing provides petroleum engineers with insight into the production potential of the reservoir and with the physical evidence of well conditions. Unexpected changes, such as extraneous water or gas production may signal well or reservoir problems. Abnormal production declines may be caused by artificial lift problems, scale buildup in the perforations, etc. All information provided by well testing enables early detection of any wellbore problems and allows the engineer to take remedial actions quickly, to ensure optimum production from a well, and to have more confidence in production changes as a result of well workovers, wellbore stimulation or treatment. In brief, accurate and timely well testing information always plays a critical role in reserve estimation, production forecasting, production optimization, capital and operational decisions during the entire development life of a reservoir.