How can you optimize reservoir performance in the face of declining production?

In my experience is always to go back to the data, improve your understanding on two critical things for the reservoir and for the wells. For the RESERVOIR, review all your hypothesis on 1- STORAGE (saturation modeling, porosity, compartmentalization, contacts and PVT) 2- FLOW (Permeability, depositional characteristics, stratigraphy, pressures and skin evolution). For the wells: 1-Conectivity (damaged perforations, saturation skin) 2-Integrity (leaking tubulars, improved extraction, proper injection if it is an injector, etc.) By doing this in an integrated manner with all the stakeholders of the tech team, you will start seeing places to improve recovery or on the contrary, know that you don′t want to invest there anymore.

In my opinion, it is all about data. Having quality reservoir data to gain a solid understanding of the sub-surface including seismic, logs and samples. Reviewing offset production if it exists to gain a good understanding of regional geological trends & variations, understanding fluid regimes. Optimal well spacing & well placement. Solid wellbore design & drilling according to well plan. Targeting & staying in the target formation. Use of modern well completion based on reservoir characteristics. Implement area specific production strategies. Ongoing reservoir surveillance and monitoring to effectively develop and produce the field. Continuously updating reservoir model. Design of effective surface production network. All need good data.

Ensure growth of production, within any asset, does not outpace team ability to steer development within a technically sound continuos improvement loop (analyze->strategize->implement->assess). The biggest gains I've often seen are produced when members of multi departments actually manage to find any time to teach/learn candidly from each other - above and beyond standard metric sharing gatherings.

In addition to all mentioned sources of information to comprehensively understand the reservoir performance, well testing is considered a vital tool to understand crucial parameters such as characterizing reservior fluid, drive mechanism, pressure profile and future response. Several mismangements for the reservior potential were basically due to not fully understand the pressure profile from testing and thus managing reservior depletion accordingly.

For offshore wells, we developed rigless wellwork framework which allowed to perform intervention activities on wells for free of rig cost. Every available well slot was used which enabled doing downhole work and improve productivity.

The use of high temperature and high pressure measurement technology in steam injection projects (Thermal EOR) constitutes a key point in the continuous and real-time monitoring of the process conditions, which is why it is of utmost importance to consider within of the budget for this type of project the installation of high P&T sensors or, failing that, the use of fiber optics for point-to-point measurement along the entire length of the well. Through the temperature profiles generated, the prospective zones of the reservoir subjected to steam injection will be determined.

Monitoring involves regularly analyzing production data, conducting well tests, and utilizing advanced technologies like downhole sensors and surveillance tools to track reservoir performance and identify potential issues.

Implement reservoir management techniques such as infill drilling, where new wells are drilled between existing ones to more effectively drain the reservoir. If the reservoir permits, re-fracturing existing wells can open new pathways for gas to flow, increasing production.

1. Presence of PDG’s in the wells will deliver continuous data of several well parameters like BHP, THP & ABP that makes easy for a reservoir engineer to understand the node relation to the whole production systems. Also, shut-in in O&G wells once a while will help you validate your reservoir in-place irrespective of the downhole completion systems. Header pressures, in addition help to see the effect of one well on the other. 2. In wells with no PDG’s, frequent lowing the manometers in candidates for gradient study or liquid level measurement can be done. However, it’s not efficient in an asset with numerous number of wells. Well wise reservoir validation becomes more difficult if the sand deposition is uneven and reservoirs are complex.

Well optimization is closely related to the completion which has been installed. Reservoir understanding should be reflected in the optimizations foreseen, such that the completion string contains the components necessary to allow for the optimization. If water breakthrough is expected, then equipment to facilitate shut-off could be installed. If hydraulic fracturing is expected to improve recovery, then the liner should be cemented. If it is expected that water blocking treatments may be pumped, then zonal intradivision of the reservoir may form part of the completion string. The optimization methods available can be very uncertain in outcome unless the well design facilitates them. Completion design must anticipate the use of the well.

One of the fundamental aspects to consider in the maintenance and/or improvement of oil production is to apply the most suitable artificial lift method in the wells, and it will be tied to the properties and reservoir capacity; therefore, it is important to carry out a screening or scenarios through respective simulations of reservoir conditions and artificial lift system, always taking care of the bottom hole pressure differential and avoiding its progressive decline through an optimized plan of pumping speeds and conditions.

Agree with Hasse. The interface between wellbore at sandface and the reservoir is sometimes neglected by those who impact decision making the most, i.e drilling departments with responsibility for Drillex and also E&P Management who makes the investment decisions and who’s KPI is governed by keeping Capex as low as possible. Also, it does not matter if you optimize a horizontal well if you end up selecting a rig which is unable to drill and complete the well effectively and to spec as recommended by the Petroleum Engineer. Make sure you select a rig that can deliver the production profiles you design for and not limit your well design and associated production profiles to fit the drilling rig.

Here are a few points to consider: 1. Enhanced Oil Recovery (EOR): Use methods like water flooding, gas injection, or chemical flooding. 2. Surfactants for Wettability Alteration: Modify reservoir wettability for enhanced fluid flow and improved oil recovery. 3. Hydraulic Fracturing Stimulation: Stimulate production in tight reservoirs through hydraulic fracturing. 4. Mitigation of Near Wellbore Damage: Minimize damage to ensure efficient fluid flow and maximize production rates. 5. Artificial Lift Techniques: Optimize systems, including Electrical Submersible Pumps (ESP), for improved fluid flow efficiency.

Wells can exibit declines in production which can be related to many issues(mostly reservoir and downhole related) here are few things to consider to rejuvinate the well: 1-Change Bean Size (choke) 2-Rerouting the well to LP or IP vessels (SEP). 3-Implementation of ALS. 4-recomplete and redesign the well. 5-Intervene for any blockages downhole or in the surface pipings.

A key point in crude oil production processes is the proper management of effluents-liquids, especially in superheated steam injection processes where these fluids are generated and are mostly discarded in areas that affect the environment; Given this diatribe, adequate effluent management technologies have been developed in which I have had the opportunity to participate through the implementation of technology for reinsertion of saturated condensate and effluents into the steam flow streams towards the well, thus contributing greater energy to the reservoir

There are many ways you can improve a declining production from the reservoir IE. 1.Reservoir pressure support by drilling more injector wells since reservoir pressure decreases upon depletion. 2.Enhanced oil recovery to increase the sweep and displacement efficiency of the reservoir fluids. 3.well stimulation designing to decrease the skin. 4.sand production control and proper completion designs

1. Utilising simulation, to optimise fluid flow dynamics and injection strategies. 2. Integrated production facilities with separators, treators & disposal units to handle diverse liquid. 3. Tailored chemical injection to avoid scaling, wax deposition and emulsions. 4. Real time monitoring systems to track fluid composition, pressure and production rates, enabling adjustments to production strategies. 5. Water flood management by balancing mobility ratio, voidage compensation, sweep efficiency, pattern designing and water quality. 6. Conducting regular fluid sampling.

Steps in designing EOR: 1. EOR Screening: There are three major categories, chemical, thermal and miscible. Preliminary Selection is made based on depth, pressure, crude properties and temperature. 2. Laboratory studies: Core studies are required for estimation of linear core displacement efficiencies. Based on the recovery factors in core, a particular EOR selection is taken ahead for simulation. 3. Pilot design: Reservoir modelling tools based on the laboratory data are used for designing pilot and commercial schemes. 4. Field execution: Envisaged and Actual field data are compared and the model is updated. Mid course corrections are planned for increasing efficacy of EOR.

One thing to consider here is that planning to implement EOR starts from day 1. it determines how you design your surface facilities, especially in offshore scenarios, and impacts the type of data you acquire throughout the primary and secondary production periods.

To enhance reservoir efficiency during declining production, utilize Enhanced Oil Recovery (EOR) methods. These advanced approaches, such as waterflooding, gas injection, and chemical flooding, optimize oil retrieval by improving fluid mobility. EOR plays a vital role in maintaining oil production and maximizing recovery from reservoirs experiencing diminishing yields.

Enhanced Oil Recovery (EOR) techniques can improve oil recovery by changing the properties of reservoir rock, reservoir fluids, or both. It is not necessary to apply EOR only in the final phase of production. In some cases, applying EOR techniques in the early stages can lead to higher recovery rates. However, many experiments conducted on a small scale in laboratories may produce interesting results, but their application in real-life scenarios is uncertain due to many uncontrollable factors. Therefore, when choosing an EOR technique for a field, it is essential to keep in mind the challenges posed by these uncontrollable factors.

Thermal EOR has been implemented for a long time; However, special attention should be focused on the steam quality, which should be greater than 95% to guarantee successful results; Therefore, a greater amount of energy will be delivered to the reservoir and consequently the oil viscosity will decrease in the drainage radius affected by the injection. Currently, mixed injection techniques of superheated steam and chemicals, as well as nanoparticles, are being implemented to further increase the oil mobility. On the other hand, the use of Advanced Steam Generators should be considered to obtain high steam quality that includes an automated mixed station to mix the saturated condensate and the steam flow stream with no energy loss.

The adoption of new technologies makes decision-making easier. The production wells generate data continuously, and analysing this data properly can help us identify hidden patterns. Additionally, deploying models can help us detect any deviation in the trend of a parameter instantly. Thanks to higher data transmission speeds, control rooms can now be set up in remote locations, saving significant costs.

Defin the formation damage is the key for the reservoir management and saving the production performance. The solution is to avoid the damage from the beginning because it will pay too much to remove it.even after the stimulation trials could be failed and loose the well.

A great advance in this field and in which I have been a participant in its application in the field is the integration of Big Data and AI in the operating philosophy of high-tech Steam Generators applied to steam injection processes in heavy oil fields from Asia and South America with excellent results, projecting itself as an effective way in making decisions and executing timely optimization actions in real time, where increases in crude oil production above 315% were obtained.

First of all the reason for the decline in production needs to be addressed , following steps can be taken : 1. Individually gauge all wells and measure their production parameters, then measure the difference between actual and declining potential. 2. Conduct bottom hole pressure survey, if possible do PBU test for estimation of reservoir properties. 3. Update well model for diagnostics. 4. Conduct remedial jobs such as (add perfs/re-perfs or acidization) to arrest declining trends. 5. Find sweet spots on the latest history matched model to arrest production decline. 6. Do economics analysis for estimation of NPV, payback period time before jumping on to any recommendation.

Verify that all previous forecasts were wrong, update the model for the 100th time, generate new forecasts, tick the box, and then ask the operator what he thinks. He'll tell you to open a few chokes, replace a few pumps over there, shut a few of those zones, and then you fill out the scorecard.

Also consider the following: Use predictive analytics to schedule maintenance activities before failures occur, minimizing downtime and maintaining optimal production levels. Collaborate with reservoir engineers, geologists, and other experts to develop a comprehensive understanding of the reservoir characteristics and devise tailored strategies for its optimization.

A análise de curvas de declínio de produ??o é um dos métodos analíticos mais utilizados por engenheiros de reservatórios para realizar ajuste de histórico e/ou previs?o de comportamento de po?os e reservatório de petróleo. Por ser um método simples sua aplica??o demanda menos tempo do que outros métodos, o que o torna particularmente útil quando se deseja realizar estudos preliminares e de rotina.

Some wells can be drilled in a isolated reservoir blocks or compartments, the knowlege of the lateral extent of the reservoir is as important as the pay thickness of the pay formation. wells closer to sealing or leaking fault might exibit fast production delicne, wells on the edge of the reservoir might experience other forms of problems (geological heterogeneity and property degradation, where this is a characteristic of geological setup closure of the petroleum system).