US20020112888A1

US20020112888A1 - Drilling system and method

Info

Publication number: US20020112888A1
Application number: US09/737,851
Authority: US
Inventors: Christian Leuchtenberg
Original assignee: Individual
Current assignee: ISG SECURE DRILLING HOLDINGS Ltd; Secure Drilling International LP
Priority date: 2000-12-18
Filing date: 2000-12-18
Publication date: 2002-08-22
Also published as: US20080041149A1; WO2002050398A1; NO326132B1; ES2244554T3; ATE298835T1; EA006054B1; US7278496B2; DE60111781D1; WO2002050398B1; US7650950B2; US20030079912A1; US20060037781A1; CA2432119C; CA2432119A1; US7044237B2; AU1932202A; AU2006252289A1; US7367411B2; AU2002219322B2; DK1356186T3

Abstract

A closed-loop drilling system and method of drilling oil, gas, or geothermal wells is described, whereby through the control of the flow rates in and out of the wellbore, and by adjusting the pressure inside the wellbore by a pressure/flow control device installed on the return line, surface pressure being increased or decreased as required, this in turn decreasing or increasing downhole pressure, occurrence of kicks and fluid losses may be greatly minimized and quickly controlled. Through the method of the invention the elimination of the kick tolerance and tripping margin on the design of the well is made possible, since the pore and fracture pressure will be determined in real-time while drilling the well, and, therefore, nearly no safety margin is necessary when designing the well, reducing significantly the number of casing strings necessary. The inventive method can be called intelligent safe drilling since the response to influx or fluid loss is nearly immediate and so smoothly done that the drilling can go on without any break in the normal course of action. The new method is applicable to the whole wellbore from the first casing string with a BOP connection, and it can be implemented and adopted to any rig or drilling installation that uses the conventional method with very few exceptions and limitations. The new method is applicable to all types of wells, onshore, offshore, deepwater and ultra-deepwater, with huge safety improvement in difficult drilling scenarios.

Description

FIELD OF THE INVENTION

The present invention deals with a closed-loop system for drilling wells where a series of equipment, for the monitoring of the flow rates in and out of the well, as well as for adjusting the back pressure, allows the regulation of the out flow so that the in and out flows are constantly balanced at all times. A pressure containment device keeps the well closed at all times. Since this provides a much safer operation, its application for exploratory wells will greatly reduce the risk of blow-outs. In environments with narrow margin between the pore and fracture pressure, it will create a step change compared to conventional drilling practice. In this context, applications in deep and ultra-deep water are included. A method for drilling, using said system, is also disclosed. The drilling system and method are suited for all types of wells, onshore and offshore.

BACKGROUND INFORMATION

Drilling oil/gas/geothermal wells has been done in a similar way for decades. Basically, a drilling fluid with a density high enough to counter balance the pressure of the fluids in the reservoir rock, is used inside the wellbore to avoid uncontrolled production of such fluids. However, in many situations, it can happen that the bottomhole pressure is reduced below the reservoir fluid pressure. At this moment, an influx of gas, oil, or water occurs, named a kick. If the kick is detected in the early stages, it is relatively simple and safe to circulate the invaded fluid out of the well. After the original situation is restored, the drilling activity can proceed. However, if, by any means, the detection of such a kick takes a long time, the situation can become out of control leading to a blowout. According to Skalle, P. and Podio, A. L. in “Trends extracted from 800 Gulf Coast blow-outs during 1960-1996” IADC/SPE 39354, Dallas, Tex., March 1998, nearly 0.16% of the kicks lead to a blowout, due to several causes, including equipment failures and human errors.

On the other hand, if the wellbore pressure is excessively high, it overcomes the fracture strength of the rock. In this case loss of drilling fluid to the formation is observed, causing potential danger due to the reduction in hydrostatic head inside the wellbore. This reduction can lead to a subsequent kick.

In the traditional drilling practice, the well is open to the atmosphere, and the drilling fluid pressure (static pressure plus dynamic pressure when the fluid is circulating) at the bottom of the hole is the sole factor for preventing the formation fluids from entering the well. This induced well pressure, which by default, is greater than the reservoir pressure causes a lot of damage, i.e., reduction of near wellbore permeability, through fluid loss to the formation, reducing the productivity of the reservoir in the majority of cases.

In the last 10 years, a new drilling technique, underbalanced drilling (UBD) is becoming more and more popular. This technique implies a concomitant production of the reservoir fluids while drilling the well. Special equipment has been developed to keep the well closed at all times, as the wellhead pressure in this case is not atmospheric, as in the traditional drilling method. Also, special separation equipment must be provided to properly separate the drilling fluid from the gas, and/or oil, and/or water and drilled cuttings.

The UBD technique has been developed initially to overcome severe problems faced while drilling, such as massive loss of circulation, stuck pipe due to differential pressure when drilling depleted reservoirs, as well as to increase the rate of penetration. In many situations, however, it will not be possible to drill a well in the underbalanced mode, e.g., in regions where to keep the wellbore walls stable a high pressure inside the wellbore is needed. In this case, if the wellbore pressure is reduced to low levels to allow production of fluids the wall collapses and drilling cannot proceed.

Since among the most dangerous events while drilling conventionally is to take a kick, there have been several methods, equipment, procedures, and techniques documented to detect a kick as early as possible. The easiest and most popular method is to compare the injection flow rate to the return flow rate. Disregarding the drilled cuttings and any loss of fluid to the formation, the return flow rate should be the same as the injected one. If there are any significant discrepancies, drilling is stopped to check if the well is flowing with the mud pumps off. If the well is flowing, the next action to take is to close the blow-out preventer equipment (BOP), check the pressures developed without circulation, and then circulate the kick out, adjusting the mud weight accordingly to prevent further influx.

This procedure takes time and increases the risk of blow-out, if the rig crew does not quickly suspect and react to the occurrence of a kick. Procedure to shut-in the well can fail at some point, and the kick can be suddenly out of control. In addition to the time spent to control the kicks and to adjust drilling parameters, the risk of a blow-out is significant when drilling conventionally, with the well open to the atmosphere at all times.

Among the methods available to quickly detect a kick the most recent ones are presented by Hutchinson, M and Rezmer-Cooper, I. in “Using Downhole Annular Pressure Measurements to Anticipate Drilling Problems”, SPE 49114, SPE Annual Technical Conference and Exhibition, New Orleans, La., 27-30 September, 1998. Measurement of different parameters, such as downhole annular pressure in conjunction with special control systems, adds more safety to the whole procedure. The paper discusses such important parameters as the influence of ECD (Equivalent Circulating Density, which is the hydrostatic pressure plus the friction losses while circulating the fluid, converted to equivalent mud density at the bottom of the well) on the annular pressure. It is also pointed out that if there is a tight margin between the pore pressure and fracture gradients, then annular pressure data can be used to make adjustments to mud weight. But, essentially, the drilling method is the conventional one, with some more parameters being recorded and controlled. Sometimes, calculations with these parameters are necessary to define the mud weight required to kill the well. However, annular pressure data recorded during kill operations have also revealed that conventional killing procedures do not always succeed in keeping the bottomhole pressure constant.

Other publications deal with methods to circulate the kick out of the well. For example, U.S. Pat. No. 4,867,254 teaches a method of real time control of fluid influxes into an oil well from an underground formation during drilling. The injection pressure p _iand return pressure p_rand the flow rate Q of the drilling mud circulating in the well are measured. From the pressure and flow rate values, the value of the mass of gas M_gin the annulus is determined, and the changes in this value monitored in order to determine either a fresh gas entry into the annulus or a drilling mud loss into the formation being drilled.

U.S. Pat. No. 5,080,182 teaches a method of real time analysis and control of a fluid influx from an underground formation into a wellbore being drilled with a drill string while drilling and circulating from the surface down to the bottom of the hole into the drill string and flowing back to the surface in the annulus defined between the wall of the wellbore and the drill string, the method comprising the steps of shutting-in the well, when the influx is detected; measuring the inlet pressure P _ior outlet pressure P_oof the drilling mud as a function of time at the surface; determining from the increase of the mud pressure measurement, the time t_ccorresponding to the minimum gradient in the increase of the mud pressure and controlling the well from the time t_c.

It is observed that in all the cited literature where the drilling method is the conventional one, the shut-in procedure is carried out in the same way. That is, literature methods are directed to the detection and correction of a problem (the kick), while there are no known methods directed to eliminating said problem, by changing or improving the conventional method of drilling wells.

Thus, according to drilling methods cited in the literature, the kicks are merely controlled. On the contrary, the present application relates to a new concept of drilling whereby a method and corresponding instrumentation allows that kicks may be detected early and controlled much quicker and safer or even eliminated/mitigated than in state-of-the-art methods.

Further, it should be noted that the present method operates with the well closed at all times. That is why it can be said that the method, herein disclosed and claimed, is much safer than conventional ones.

In wells with severe loss of circulation, there is no possibility to detect an influx by observing the return flow rate. Schubert, I. J. and Wright, J. C. in “Early kick detection through liquid level monitoring in the wellbore”, IADC/SPE 39400, Dallas, Tex., March 1998 propose a method of early detection of a kick through liquid level monitoring in the wellbore. Having the wellbore open to atmosphere, here again the immediate step after detecting a kick is to close the BOP and contain the well.

The excellent review of 800 blow-outs occurred in Alabama, Texas, Louisiana, Mississipi, and offshore in the Gulf of Mexico cited hereinbefore by Skalle, P. and Podio, A. L. in “Trends extracted from 800 Gulf Coast blow-outs during 1960-1996” IADC/SPE 39354, Dallas, Tex., March 1998 shows that the main cause of blow-outs is human error and equipment failure.

Nowadays, more and more oil exploration and production is moving towards challenging environments, such as deep and ultra-deepwater. Also, wells are now drilled in areas with increasing environmental and technical risks. In this context, one of the big problems today, in many locations, is the narrow margin between the pore pressure (pressure of the fluids—water, gas, or oil—inside the pores of the rock) and the fracture pressure of the formation (pressure that causes the rock to fracture). The well is designed based on these two curves, used to define the extent of the wellbore that can be left exposed, i.e., not cased off with pipe or other form of isolation, which prevents the direct transmission of fluid pressure to the formation. The period or interval between isolation implementation is known as a phase.

In some situations a collapse pressure (pressure that causes the wellbore wall to fall into the well) curve is the lower limit, rather than the pore pressure curve. But, for the sake of simplicity, just the two curves should be considered, the pore pressure and fracture pressure one. A phase of the well is defined by the maximum and minimum possible mud weight, considering the curves mentioned previously and some design criteria that varies among the operators, such as kick tolerance and tripping margin. In case of a kick of gas, the movement of the gas upward the well causes changes in the bottomhole pressure. The bottomhole pressure increases when the gas goes up with the well closed. Kick tolerance is the change in this bottomhole pressure for a certain volume of gas kick taken.

Tripping margin, on the other hand, is the value that the operators use to allow for pressure swab when tripping out of the hole, to change a bit, for example. In this situation, a reduction in bottomhole pressure, caused by the upward movement of the drill string can lead to an influx.

According to FIG. 1 attached, based on state-of-the-art designing of wells for drilling, typically a margin of 0.3 pound per gallon (ppg) is added to the pore pressure to allow a safety factor when stopping circulation of the fluid and subtracted from the fracture pressure, reducing even more the narrow margin, as shown by the dotted lines. Since the plot shown in FIG. 1 is always referenced to the static mud pressure, the compensation of 0.3 ppg allows for the dynamic effect while drilling also. The compensation varies from scenario to scenario but typically lies between 0.2 and 0.5 ppg.

From FIG. 1, it can be seen that the last phase of the well can only have a maximum length of 3,000 ft, since the mud weight at this point starts to fracture the rock, causing mud losses. If a lower mud weight is used, a kick will happen at the lower portion of the well. It is not difficult to imagine the problems created by drilling in a narrow margin, with the requirement of several casing strings, increasing tremendously the cost of the well. In some critical cases, a difference as small as 0.2 ppg is found between the pore and fracture pressures. Moreover, the current well design shown in FIG. 1 does not allow to reach the total depth required, since the bit size is continuously reduced to install the several casing strings needed. In most of these wells, drilling is interrupted to check if the well is flowing, and frequent mud losses are also encountered. In many cases wells need to be abandoned, leaving the operators with huge losses.

These problems are further compounded and complicated by the density variations caused by temperature changes along the wellbore, especially in deepwater wells. This can lead to significant problems, relative to the narrow margin, when wells are shut in to detect kicks/fluid losses. The cooling effect and subsequent density changes can modify the ECD due to the temperature effect on mud viscosity, and due to the density increase leading to further complications on resuming circulation. Thus using the conventional method for wells in ultra deep water is rapidly reaching technical limits.

On the contrary, in the present application the 0.3 ppg margins referred to in FIG. 1 are dispensed with during the planning of the well since the actual required values of pore and fracture pressures will be determined during drilling. Thus, the phase of the well can be further extended and consequently the number of casing strings required is greatly reduced, with significant savings. If the case of FIG. 1 is considered, the illustrated number of casings is 10, while by graphically applying the method of the invention this number is reduced to 6, according to FIG. 2 attached. This may be readily seen by considering only the solid lines of pore and fracture gradient to define the extent of each phase, rather than the dotted lines denoting the limits that are in conventional use..

In order to overcome these problems, the industry has devoted a lot of time and resources to develop alternatives. Most of these alternatives deal with the dual-density concept, which implies a variable pressure profile along the well, making it possible to reduce the number of casing strings required.

The idea is to have a curved pressure profile, following the pore pressure curve. There are two basic options:

injection of a lower density fluid (oil, gas, liquid with hollow glass spheres) at some point;

placement of a pump at the bottom of the sea to lift the fluid up to the surface installation.

There are advantages and disadvantages of each system proposed above. The industry has mainly taken the direction of the second alternative, due to arguments that well control and understanding of two-phase flow complicates the whole drilling operation with gas injection.

Thus, according to the IADC/SPE 59160 paper “Reeled Pipe Technology for Deepwater Drilling Utilizing a Dual Gradient Mud System”, by P. Fontana and G. Sjoberg, it is possible to reduce casing strings required to achieve the final depth of the well by returning the drilling fluid to the vessel with the use of a subsea pumping system. The combination of seawater gradient at the mud line and drilling fluid in the wellbore results in a bottomhole equivalent density that can be increased as illustrated in FIG. 2 of the paper. The result is a greater depth for each casing string and reduction in total number of casing strings. It is alleged that larger casing can then be set in the producing formation and deeper overall well depths can be achieved. The mechanism used to create a dual gradient system is based on a pump located at the sea bottom.

However, there are several technical issues to be overcome with this option, which will delay field application for some years. The cost of such systems is also another negative aspect. Potential problems with subsea equipment will make any repair or problem turn into a long down-time for the rig, increasing even further the cost of exploration.

There are three other main methods of closed system drilling: a) underbalanced flow drilling, which involves flowing fluids from the reservoir continuously into the wellbore is described and documented in the literature; b) mud-cap drilling, which involves continuous loss of drilling fluid to the formation, in which fluid can be overbalanced, balanced or underbalanced is also documented; c) air drilling, where air or other gas phase is used as the drilling fluid. These methods have limited application, i.e., underbalanced and air drilling are limited to formations with stable wellbores, and there are significant equipment and procedural limitations in handling produced effluent from the wellbore. The underbalanced method is used for limited sections of the wellbore, typically the reservoir section. This limited application makes it a specialist alternative to conventional drilling under the right conditions and design criteria. Air drilling is limited to dry formations due to its limited capability to handle fluid influxes. Similarly Mud-Cap drilling is limited to specific reservoir sections (typically highly fractured vugular carbonates).

Thus, the open literature is extremely rich in pointing out methods for detecting kicks, and then methods for circulating kicks out of the wellbore. Generally all references teach methods that operate under conventional drilling conditions, that is, with the well being open to the atmosphere. However, there is no suggestion nor description of a modified drilling method and system, which, by operating with the well closed, controlling the flow rates in and out of the wellbore, and adjusting the pressure inside the wellbore as required, causing that influxes (kicks) and fluid losses do not occur or are extremely minimized, such method and system being described and claimed in the present application.

SUMMARY OF THE INVENTION

In its broadest aspect the present invention is directed to a system and method of drilling a well by monitoring the flow in and out of the well, as well as monitoring of the flow rates in and out, together with other parameters that produce an early detection of influx or loss independent of the mass flow in and out at that point in time, the well drilled being closed with a pressure containment device at all times. Monitoring of flow may be by measurement of mass and/or volume flow. In a particularly preferred embodiment the system and method of the invention comprises monitoring the mass flow in and out of the well. Preferably monitoring is constant throughout a given drilling operation.

The back pressure in the well is automatically adjusted by pressure/flow control device, controlled by a central control device. This central control device regulates the out flow to keep the flows in and out balanced at all times, or to preemptively adjust the backpressure to change the ECD (Equivalent Circulating Density) instantaneously in response to an early detection of influx or fluid loss.

Accordingly the system of the present invention for drilling a well while injecting a drilling fluid through an injection line of said well and recovering through a return line of said well where the well being drilled is closed at all times comprises a pressure containment device and pressure/flow control device to a wellbore to establish/maintain a back pressure on the well, means to monitor the fluid flow in and out, means to monitor flow of any other material in and out, means to monitor parameters affecting the monitored flow value and means to predict a calculated value of flow out at any given time and to obtain real time information on discrepancy between predicted and monitored flow out and converting to a value for adjusting the pressure/flow control device and restoring the predicted flow value.

In a further aspect the corresponding method of the present invention comprises, in relation to the system of the invention as hereinbefore defined, the following steps of injecting drilling fluid through said injection line through which said fluid is made to contact said means for monitoring flow and recovering drilling fluid through said return line; collecting any other material at the surface; measuring the flow in and out of the well and collecting flow and flow rate signals; measuring parameters affecting the monitored flow value and means; directing all the collected flow, correction and flow rate signals to the said central data acquisition and control system; monitoring parameters affecting the monitored flow value and means to predict a calculated value of flow out at any given time and to obtain real time information on discrepancy between predicted and monitored flow out and converting to a value for adjusting the pressure/flow control device and restoring the predicted flow value.

We have found by means of the system and method of the invention that the generation of real time metering using a full mass balance and time compensation as a dynamic predictive tool, which can be compensated also for any operational pause in drilling or fluid injection enables for the first time an adjustment of fluid injection rate while continuing normal operations. This is in contrast to known open well methods which require pausing fluid injection and drilling to unload excess fluid, and add additional fluid, by trial and error until pressure is restored, which can take a matter of hours of fluid circulation to restore levels. Moreover the system and method provide for the first time a means for immediate restoration of pressure, by virtue of the use of a closed system whereby addition or unloading of fluid immediately affects the well backpressure.

We have also found that the system and method of the invention provide additional advantages in terms of allowing operation with a reduced reservoir volume of fluid, by virtue of closed operation under back pressure. Moreover the system and method can be operated efficiently, without the need for repeated balancing of the system after any operational pause in drilling, by virtue of the ability to continuously circulate fluid even during pauses in drilling, avoiding any undue changes in fluid density and temperature.

Preferably the system for drilling a well while injecting a drilling fluid through an injection line of said well and recovering through a return line of said well where the well being drilled is closed at all times comprises:

a) a pressure containment device;

b) a pressure/flow control device on the outlet stream;

c) means for measuring mass and/or volumetric flow and flow rate on the inlet and outlet streams to obtain real time mass or volumetric flow signals;

d) means for measuring mass and/or volumetric flow and flow rate of any other materials in and out;

e) means for directing all the flow, pressure and temperature signals so obtained to a central data acquisition and control system; and

g) a central data acquisition and control system programmed with a software that can determine a real time predicted out flow and compare it to the actual out flow estimated from the mass and volumetric flow rate values and other relevant parameters.

Preferably the means c) for measuring mass flow comprises a volume flow meter and at least one pressure sensor to obtain pressure signals and at least one temperature sensor to obtain temperature signals; and may be a mass flow meter comprising integral pressure and temperature sensors to compensate for changes in density and temperature; and the means c) for measuring flow rate comprises means for assessing the volume of the hole at any given time, as a dynamic value having regard to the continuous drilling of the hole. At least one additional pressure and temperature sensor may be provided to monitor other parameters that produce an early detection of influx or loss independent of the mass flow in and out at that point in time.

Preferably the means d) comprise means for measuring cuttings volume/mass out.

Most preferably the system comprises:

a) a pressure containment device;

b) a pressure/flow control device on the outlet stream;

c) means for measuring mass flow rate on the inlet and outlet streams;

d) means for measuring volumetric flow rate on the inlet and outlet streams;

e) at least one pressure sensor to obtain pressure data;

f) at least one temperature sensor to obtain temperature data;

g) a central data acquisition and control system that sets a value for an expected out flow and compares it to the actual out flow estimated from data gathered by the mass and volumetric flow rate meters as well as from pressure and temperature data, and in case of a discrepancy between the expected and actual flow values, adjusting the said pressure/flow control device to restore the outflow to the expected value.

In a further aspect of the invention there is provided a method for drilling a well while injecting a drilling fluid through an injection line of said well and recovering through a return line of said well where the well being drilled is closed at all times comprising the following steps:

a) providing a pressure containment device, suitably of a type that allows passage of pipe under pressure, to a wellbore;

b) providing a pressure/flow control device to control the flow out of the well and to keep a back pressure on the well;

c) providing a central data acquisition and control system and related software;

d) providing mass flow meters in both injection and return lines;

e) providing flow rate meters in both injection and return lines;

f) providing at least one pressure sensor;

g) providing at least one temperature sensor;

h) injecting drilling fluid through said injection line through which said fluid is made to contact said mass flow meters, said fluid flow meters and said pressure and temperature sensors, and recovering drilling fluid through said return line;

i) collecting drill cuttings at the surface;

j) measuring the mass flow in and out of the well and collecting mass flow signals;

k) measuring the fluid flow rates in and out of the well and collecting fluid flow signals;

l) measuring pressure and temperature of fluid and collecting pressure and temperature signals;

m) directing all the collected flow, pressure and temperature signals to the said central data acquisition and control system;

n) the software of the central data acquisition and control system considering, at each time, the predicted flow out of the well taking into account several parameters;

o) having the actual and predicted out flows compared and checked for any discrepancy, compensated for time lags in between input and output;

p) in case of a discrepancy, having a signal sent by the central data acquisition and control system to adjust the pressure/flow control device and restore the predicted out flow rate, without interruption of the drilling operation.

Optionally the method comprises additionally providing a means of measurement of drill cuttings rate, mass or volume, when required, to measure the rate of cuttings being produced from the well.

Preferably the system and method comprise additionally means to pressurize the wellbore through the annulus, and a step of pressurising the wellbore through the annulus, independently of the current fluid injection path.

Therefore, the present invention provides a safe method for drilling wells, since not only is the well being drilled closed at all times, but also any fluid loss or influx that occurs is more accurately and faster determined and subsequently controlled than in state-of-the-art methods.

One advantage of the present method over state-of-the-art methods is that it is able to instantly change the ECD (Equivalent Circulating Density) by adjusting the backpressure on the wellbore by closing or opening the pressure/flow control device. In this manner the method herein described and claimed incorporates early detection methods of influx/loss that are existing or yet to be developed as part of the method herein described and claimed, e.g., tools under development or that may be developed that can detect trace hydrocarbon influx, small temperature variations, pressure pulses etc. The output of these tools or technology that indicates a kick or fluid loss can be used as a feedback parameter to yield an instant reaction to the detected kick or fluid loss, thus controlling the drilling operation at all times.

As a consequence, in a patentably distinguishing manner, the method of the invention allows that drilling operations be carried out in a continuous manner, while in state-of-the-art methods drilling is stopped and mud weight is corrected in a lengthy, time-consuming step, before drilling can be resumed, after a kick or fluid loss is detected.

This leads to significant time savings as the traditional approach to dealing with influxes is very time-consuming: stopping drilling, shutting in the well, observing, measuring pressures, circulating out the influx by the accepted methods, and adjusting the mud weight. Similarly a loss of drilling fluid to the formation leads to analogous series of time-consuming events.

The present invention provides also a method of drilling where the bottomhole pressure can be very close to the pore pressure, thus reducing the overbalanced pressure usually applied on the reservoir, and consequently reducing the risk of fluid losses and subsequent contamination of the wellbore causing damage, the overall effect being that the well productivity is increased.

The present invention provides further a method to drill with the exact bottomhole pressure needed, with a direct determination of the pore pressure.

The present invention provides also a method for the direct determination of the fracture pressure if needed.

Since both the fracture and pore pressure curves are estimated and usually are not accurate, the present invention allows a significant reduction of risk by determining either the pore pressure or the fracture pressure, or, in more critical situations, both the pore and fracture pressure curves in a very accurate mode while drilling the well. Therefore by eliminating uncertainties from pore and fracture pressures and being able to quickly react to correct any undesired event, the present method is consequently much safer than state-of-the-art drilling methods.

The present invention provides further a drilling method where the elimination of the kick tolerance and tripping margin on the design of the well is made possible, since the pore and fracture pressure will be determined in real time while drilling the well, and, therefore, no safety margin or only a small one is necessary when designing the well. The kick tolerance is not needed since there will be no interruption in the drilling operation to circulate out any gas that might have entered into the well. Also, the tripping margin is not necessary because it will be replaced by the back pressure on the well, adjusted automatically when stopping circulation.

By the fast detection of any influx and by having the well closed and under pressure at all times while drilling, the present invention allows the well control procedure to be much simpler, faster, and safer, since no time is wasted in checking the flow, closing the well, measuring the pressure, changing the mud weight if needed, and circulating the kick out of the well.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 attached is a state-of-the-art log of pore and fracture pressure curves indicated hereinbefore. Included in this figure are the kick tolerance and tripping margin, used for designing the casing setting points, in this case taken as 0.3 ppg below the fracture pressure and above the pore pressure, respectively. This value is commonly used in the industry. On the right hand side the number and diameter of the casing strings required to safely drill this well using the current conventional drilling method is shown. As pointed out before, the two curves shown are estimated before drilling. Actual values might never be determined by the current conventional drilling method. [0085]
FIG. 2 attached is a log of the same curves according to the invention, without the kick tolerance and tripping margin of 0.3 ppg included. On the right hand side the number of casing strings required can be seen. With the drilling method described in the present application the elimination of the kick tolerance and tripping margin on the design of the well is made possible, since the pore and fracture pressure will be determined in real time while drilling the well, with the well being drilled closed at all times, and, therefore, no safety margin is necessary when designing the well. [0086]
FIG. 3 attached is a state-of-the-art schematics of the circulating system of a standard rig, with the return flow open to the atmosphere. [0087]
FIG. 4 attached is a schematic of the circulating system of a rig with the drilling method described in the application. A pressure containment device located at the wellhead, mass flow and fluid flow rate meters on the inlet and outlet streams, pressure and temperature sensors, cuttings mass/volume measurement device, and other pieces of equipment have been added to the standard drilling rig configuration. The control system receives all the data gathered and actuates the pressure/flow control device on the outlet stream. [0088]
FIG. 5 attached is a general block diagram of the method described in the present invention. [0089]
FIG. 6 attached is a flowsheet that schematically illustrates the method of the invention.[0090]

PREFERRED MODE—DETAILED DESCRIPTION

As pointed out hereinbefore, the present system and method of drilling wells is based on a closed-loop system. The inventive method and system is applied to oil and gas wells, as well as to geothermal wells. [0091]
As regards the mud circuit, the circulation of the drilling fluid down the wellbore may be through the drill string and the return through the annulus, as in state-of-the-art methods, but not limited to it. As a matter of fact, any way of circulation of the drilling fluid may be successfully employed in the practice of the present system and method, no matter where the fluids are injected or returned. [0092]
In a very broad way, the system and method of the invention comprises adjusting the wellbore pressure with the aid of a pressure/flow control device to correct the bottomhole pressure to prevent fluid influx or losses in a pro-active as opposed to the state-of-the-art reactive manner. [0093]
While several of the devices being described have been used in some configuration or combination, and several of the parameter measurements have been included in descriptive methods on patents or literature, none have ever: [0094]
1. Simultaneously combined the measurement of all critical parameters to ensure the necessary accuracy required allowing such a system to effectively function as a whole method. [0095]
2. Utilized mass flow meters simultaneously on inlet and outlet flows. [0096]
3. Utilized mass measurement of cuttings in conjunction with mass flow measurement on inlet and outlet. [0097]
4. Utilized a pressure/flow control device as an instant control of ECD during drilling for the purpose of preventing and controlling influx or losses. [0098]
5. Defined the use of a pressure/flow control device as a pro-active method for adjusting ECD based on early detection of influx/loss events. [0099]
The method and system of the invention will now be described in more detail based on the appended FIGURES. [0100]
FIG. 3 illustrates a drilling method according to state-of-the-art techniques. Thus, a drilling fluid is injected through the drill string ([0101] 1), down the wellbore through the bit (2) and up the annulus (3). At the surface the fluid that is under atmospheric pressure is directed to the shale shaker (4) for solid/liquid separation. The liquid is directed to the mud tank (5) from where the mud pumps (6) suck the fluid to inject it through the drill string (1) and close the circuit. In case of a kick, normally detected by mud tank volume variation indicated by level sensors (7), the BOP (8) must be closed to allow kick control. At this point the drilling operation is stopped to check pressure and adjust the mud weight to avoid further influxes. Improvements in state-of-the-art drilling methods are generally directed to, for example, improve the measurement of volume increase or decrease in tank (5). However, such improvements bring only minor changes to the kick detection procedure; furthermore, no fundamental modifications are known directed to the improvement of safety and/or to keeping the drilling method continuous, this modification being only brought about by the present invention.
On the contrary, according to FIG. 4 that illustrates one embodiment of the invention, the drilling fluid is injected through the drill string ([0102] 1), going down towards the bottom hole through the bit (2) and up the annulus (3) and is diverted by a pressure containment device (26) through a closed return line (27) under pressure. BOP (8) remains open during drilling. The fluid is made to contact pressure and temperature sensors (9), fluid flow meter (10), mass flow meter (11), flow/pressure control device (12), degasser (13) then to the shale shaker (4). The shale shaker (4) separates the cuttings (drill solids) from the liquid and the solids have their mass/volume determined (19) while the liquid is directed to the mud tank (5) having the mass/volume determined as well (20). All standard drilling parameters are acquired by a device (21) normally called mud logging. Downhole parameters are acquired by a device (24) located close to the bit (2). The mass/volume of gas separated in degasser (13) is measured by a device (25).
The drilling fluid is injected with the aid of pump ([0103] 6) through an injection line (14) through which said fluid is made to contact mass flow meter (15), fluid flow meter (16), pressure and temperature sensors (17). Devices (7), (9), (10), (11), (15), (16), (17), (19), (20), (21), (24), (25) all acquire data as signals that are directed to a central data acquisition and control system (18). System (18) sends a signal to the pressure/flow control device (12) to open or close it. Whenever it is deemed necessary, a pump (23) may send fluid directly to the annulus (3) through a dedicated injection line (22) via a mass flow meter (28), fluid flow meter (28) and pressure and temperature sensors (28). For figure simplification these three devices are shown in just one piece of equipment. This injection line may be incorporated as part of the standard circulation system, or embodied in other ways, the purpose being to provide an independent, of normal drilling circulation, means of flow into wellbore. The central data acquisition and control system (18) acquires data from device (28).
According to the concept of the present invention, as illustrated in FIG. 4, a pressure containment device ([0104] 26) diverts the drilling fluid and keeps it under pressure. Device (26) may be a rotating BOP or a rotating control head, but not limited to it. The location of device (26) is not critical. It may be located at the surface or at some point further down e.g. on the sea floor, inside the wellbore, or at any other suitable location. The drilling fluid is diverted to a closed pipe (27) and then to a surface system. The type and design of the device (26) is not critical and depends on each well being drilled. It is a standard equipment that is commercially available or readily adapted from existing designs.
As described hereinbefore, upon a signal received from control system ([0105] 18) the pressure/flow control device (12) opens or closes to allow decrease or increase of the backpressure at the well head so that the outflow can be restored to the predicted value determined by system (18). Two or more of these pressure/flow control devices (12) can be installed in parallel with isolation valves to allow redundant operation. Devices (12) can be positioned downstream of the pressure containment device (26) at any suitable point in the surface system. Some surface systems may incorporate two or more of such devices (12) at different nodes.
One critical aspect of the present method is the accurate measurement of the injected and returned mass and fluid flow rates. The equipment used to carry out such measurement is mass flow meters ([0106] 11,15) and fluid flow meters (10,16). The equipment is installed in the injected (14) and return (27) fluid lines. These meters may also be installed at the gas outlet (25) of the degasser (13) and somewhere (20) on the fluid line between shale shaker (4) and tank (5). Also they may be installed on the independent injection line (22). The mass and fluid flow meters are commercially available equipment. Multi-phase meters are also commercially available and may be used. The precision of this equipment, allows accurate measurement, subsequent control and safer drilling.
To further improve the accuracy of the method the cuttings mass/volume rate can be measured by commercially available equipment ([0107] 19) to verify that the mass of cuttings being received back at the surface is correlated with the rate of penetration and wellbore geometry. This data allows correction of the mass flow data and allows identification of trouble events.
The measurements of mass and fluid flow rates provide data that are collected and directed to a central data acquisition and control system ([0108] 18).
The central data acquisition and control system ([0109] 18) is provided with a software designed to predict an expected, ideal value for the outflow, said value being based on calculations taking into account several parameters including but not restricted to rate of penetration, rock and drilling fluid density, well diameter, in and out flow rates, cuttings return rate, bottomhole and wellhead pressures and temperatures.
Said software compares the said predicted ideal value with the actual, return flow rate value as measured by the mass flow meters ([0110] 11,15) and fluid flow meters (10,16). If the comparison yields any discrepancy, the software automatically sends a command to a pressure/flow control device (12) designed to adjust the return flow rate so as to restore the said return flow rate to the predicted, ideal value.
Said software can also receive as input any early detection parameters available or being developed or capable of being developed. Such input will trigger a chain of investigation of probable scenarios, checking of actual other parameter and any other means (databased or software or mathematical) to ascertain that an influx/loss event has occurred. Said software will in such cases pre-emptively adjust backpressure to immediately control the event. [0111]
Said software will allow for override of the standard detection (state-of-the-art) by the early detection system of the invention and will compensate and filter for any conflict in fluid/mass flow indication. [0112]
Said software may have filters, databases, historical learning and/or any other mathematical methods, fuzzy logic or other software means to optimize control of the system. [0113]
The pressure/flow control device ([0114] 12) used to restore the ideal flow is an equipment chosen according to the well parameters such as diameter of the return line, pressure and flow requirements. The pressure/flow control device (12) is, as previously stated, standard, commercially available equipment. Alternatively, it may be specifically designed for the required purpose.
According to the present method, the flow rates in and out of the wellbore are controlled, and the pressure inside the wellbore is adjusted by the pressure/flow control device ([0115] 12) installed on the return line (27) or further downstream in the surface system.
Thus, if the drilling fluid volume returning from the wellbore is increasing, after compensating for all possible factors it is a sign that an influx is happening. In this case the surface pressure should be increased to restore the bottomhole pressure in such a way as to overcome the reservoir pressure. [0116]
On the other hand, if the fluid volume returning is decreasing, after compensating for all possible factors it means the pressure inside the wellbore is higher than the fracture pressure of the rock, or that the sealing of the drilling mud is not effective. Therefore, it is necessary to reduce the wellbore pressure, and the reduction will take place by lowering the surface back pressure sufficiently to restore the normal condition. [0117]
If an early detection signal is confirmed, control system ([0118] 18) will proactively adjust the backpressure by opening or closing pressure/flow control device (12) to suit the occurred event.
Thus, upon any undesired event, the system acts in order to adjust the rate of return flow and/or pressure thus increasing or decreasing the backpressure, while creating the desired condition downhole of no inflow from the exposed formation or no loss of fluid to the same exposed formation. This is coupled with a feedback loop to constantly monitor the reaction to each action, as well as the necessary software design, and any necessary decision system including but not limited to databases and fuzzy logic filters to ensure consistent operation. [0119]
The system and method of drilling oil, gas and geothermal wells according to the present invention is based on the principle of mass conservation, a universal law. [0120]
While drilling a well, loss of fluid to the rock or influx from the reservoir is common, and should be avoided to eliminate several problems. By applying the principle of mass conservation, the difference in mass being injected and returned from the well, compensated for increase in hole volume, additional mass of rock returning and other relevant factors, including but not limited to thermal expansion/contraction and compressibility changes, is a clear indication of what is happening downhole. [0121]
Therefore, the expression “mass flow” as used herein means the total mass flow being injected and returned, comprised of liquid, solids, and possibly gas. [0122]
In order to increase the accuracy of the method and to expedite detection of any undesired event, the flow rates in and out of the well are also monitored at all times. This way, the calculation of the predicted, ideal return flow of the well can be done with a certain redundancy and the detection of any discrepancy can be made with reduced risks. [0123]
It should be understood that all the devices used in the present system and method, such as flow metering system, pressure containment device, pressure and temperature sensors, pressure/flow control device are commercial devices and as such do not constitute an object of the invention. [0124]
Further, it is within the scope of the application that any improvements in mass/flow rate measurements or any other measuring device can be incorporated into the method. Also comprised within the scope of the application are any improvements in the accuracy and time lag to detect influx or fluid losses as well as any improvements in the system ([0125] 18) to manipulate the data and make decisions related to restore the predicted flow value.
Thus, improved detection, measurement or actuation tools are all comprised within the scope of the application. [0126]
It has been shown that measurement of the flow rate only is not accurate enough to provide a clear indication of losses or gains while drilling. That is why the present method envisages the addition of an accurate mass flow metering ([0127] 11,15) system that allows the present drilling method to be much safer than state-of-the-art drilling methods.
This mass flow metering principle is extended to include other subcomponents of the system where accuracy can be improved, such as, but not limited to measuring the mass flux of cuttings ([0128] 19) being produced at the shakers (4) and mass outflow of gas (25) from degasser (13), to allow verification and/or improvement of the mass balance being continuously applied to the system.
Another very important device used in the method and system of this invention is the pressure containment equipment ([0129] 26), to keep the well flowing under pressure at all times. By controlling the pressure inside the well with a pressure/flow control device (12) on the return line (27) the bottomhole pressure can be quickly adjusted to the desired value so as to eliminate the losses or gains being detected.
By having a pressure sensor ([0130] 24) at the bottom of the string (1) and another one (9) at the surface, the pore and fracture pressures of the formations can be directly determined, dramatically improving the accuracy of such pressure values.
The assessment of the pore and fracture pressures according to the method of the invention is carried out the following way: if the central data acquisition and control system ([0131] 18) detects any discrepancy and a decision to actuate the pressure/flow control device (12) is made, it is a sign that either a fluid loss or influx is occurring. The Applicant has thus ascertained that if there is a fluid loss this means that the bottomhole pressure being recorded is equivalent to the fracture pressure of the formation.
On the contrary, if an influx is detected, this means that the bottomhole pressure being recorded is equivalent to the pore pressure of the formation. [0132]
Further, in case of the absence of the pressure sensor in the bottomhole, the variables pore pressure and fracture pressure can be estimated. Thus, the bottomhole pressure is not one of the variables being recorded and only the wellhead or surface pressure is the pressure variable being acquired. The pore pressure and the fracture pressure can then be indirectly estimated by adding to the obtained value the hydrostatic head and friction losses within the wellbore. [0133]
The software pertaining to the central data and control system ([0134] 18) would include all the necessary algorithms, empirical correlations or other method to allow accurate estimation of the hydrostatic head and friction losses including any transient effects like, but not limited to, changing temperature profile along the wellbore.
Usually, indirect estimation made before drilling, based on correlations from logs, or during drilling using drilling parameters are the best alternatives to determine the pore pressure. Similarly, fracture pressure is also indirectly estimated from logs before drilling. In some situations the fracture pressure is determined at certain points while drilling, usually when a casing shoe is set, not along the whole well. [0135]
Advantageously, when using the method and system of the invention the pore and fracture pressure may be directly determined while drilling the well. This entails great savings as regards safety and time, two parameters of utmost importance in drilling operations. [0136]
In state-of-the-art methods, the bottomhole pressure is adjusted by increasing or reducing the mud weight. The increase or reduction in mud weight is most of the time effected based on quasi-empirical methods, which by definition implies inaccuracies, which are handled by an iterative process of: —adjusting mud weight, measuring mud weight—this process being repeated until the desired value is reached. To further complicate the matter, due to the time lag, caused by the circulation time (i.e., time for a full loop movement of a unit element of mud), the adjustments must be made in stages, e.g., in order to quickly contain an influx, a higher density mud is introduced into the system to produce an increase in ECD (Equivalent Circulating Density). At the point where additional hydrostatic head of this higher density mud, coupled with the hydrostatic head of lower density mud, initially in circulation, becomes close to being sufficient to contain the influx, another variation in density of mud must be executed in order not to increase the ECD to the point of creating losses. This is further complicated by the fact that such density adjustments affect the rheology (viscosity, yield point, etc.) of the mud system leading to changes in the friction component, which in turn has a direct effect on the ECD. So, in practice, the adjustment of mud weight is not always successful in restoring the desired equilibrium of fluid circulation in the system. Inaccuracy, depending on its extent, may lead to hazardous situations such as blowouts. [0137]
On the contrary, the method and system of the invention allows for a precise adjustment of increase or reduction in bottomhole pressure. By using the pressure/flow control device ([0138] 12) to restore the equilibrium and pressures inside the wellbore, the adjustment is much faster achieved, avoiding the hazardous situation of well-known methods.
It should also be pointed out that in state-of-the-art methods the needed bottomhole pressures needed to restore the equilibrium are estimated under static conditions, since these determinations are made without fluid circulation. However, the influxes or fluid losses are events that occur under dynamic conditions. This implies in even more errors and inaccuracies. [0139]
Also the speed of adjustment is much greater in the present method, as opposed to the conventional situation, where increasing the density (weighting up) or decreasing the density (cutting back) is a very time consuming process. It has been cited before that while drilling the ECD is the actual pressure that needs to overcome the formation pressure to avoid influx. However, when the circulation is stopped to make a connection, for example, the friction loss is zero and thus the ECD reduces to the hydrostatic value of the mud weight. In scenarios of very narrow mud window, the margin can be as low as 0.2 ppg. In these cases, it is common to observe influxes when circulation is interrupted, increasing substantially the risks of drilling with the conventional drilling system. [0140]
On the contrary, since the present method operates with the well closed at all times which implies a back pressure at all times, this back pressure may be adjusted to compensate for dynamic friction losses when the mud circulation is interrupted, avoiding the influx of reservoir fluids (kick). Thus the improved safety of the method of the invention relative to the state-of-the-art drilling methods may be clearly seen. [0141]
Replacement of the dynamic friction loss when the pump stops can be accomplished by slowly reducing the circulation rate through the normal flow path and simultaneously closing the pressure flow/contol device and trapping a backpressure that compensates for the loss in friction head. [0142]
This same purpose of keeping an unchanging pressure at the bottomhole during circulation stops can be more readily achieved by the following method: the back pressure adjustment can be applied by pumping fluid, independent of the normal circulating flow path, into the wellbore, to compensate for the loss in friction head, and effecting a continuous flow that allows easy control of the back pressure by adjustment of the pressure/flow control device ([0143] 12). This fluid flow may be achieved completely independent of the normal circulating path by means of a mud pump (23) and injection line (22).
Therefore, a circulation bypass composed of a pump ([0144] 23) and a dedicated injection line (22) to the wellbore annulus allows keeping a constant pressure downhole during circulation stops and continuously detecting any changes in the mass balance indicative of an influx or loss during the circulation stop.
By using the method and system of the invention, the errors from estimating the required mud weight based on static conditions are avoided since the measurements are effected under the same dynamic conditions as those when the actual events occur. [0145]
This method also renders possible to run the mud density at a value slightly lower than that required to balance the formation pressure and using the backpressure on the well to exert an extremely controllable ECD at the bottomhole that has the flexibility to be instantaneously adjusted up or down. This will be the preferred method in wells with very narrow pore pressure/fracture pressure margins as occur in some drilling scenarios. [0146]
In this case one of the parameters mentioned in Table 1, which is the advantage of having three safety barriers is negated. However, the current technical limit on some ultra-deep water wells, due to the narrow margin, when drilling with the state-of-the art method, leads to a sequence of fluid influxes/losses due to the inaccuracies in manually controlling the mud density and subsequent ECD as described above, that can lead to loss of control of the drilling situation and has resulted in the abandonment of such wells due to the safety risks and technical inability to recover from the situation. [0147]
However, the method of the invention allows, by creating an instant control mud weight window, controlling the ECD by increasing or decreasing the backpressure, controlled by the positioning of the pressure/flow control device, to create the conditions for staying within the narrow margin. This results in the technical ability to drill wells in very adverse conditions as in narrow mud weight window, under full control with the consequent improvement in safety as the well is at all times in a stable circulating condition, while still retaining two barriers ie. the BOP (blow-out preventer), and the pressure containment device. [0148]
The central data acquisition and control system ([0149] 18) has a direct output for actuation of the pressure/flow control device(s) (12) downstream the wellhead opening or closing the flow out of the well to restore the expected value. At this point, if an action is needed, the bottomhole pressure is recorded and associated to the pore or fracture pressure, if a gain or loss is being observed, respectively.
In case an influx of gas occurs, the circulation of the gas out of the well is immediately effected. By closing the pressure/flow control device ([0150] 12) to restore the balance of flow and the predicted value, the bottomhole pressure reaches back a value that avoids any further influx. At this point no more gas will enter the well and the problem is limited to circulating out the small amount of gas that might have entered the well. Since the well that is being drilled is closed at all times, there is no need to stop circulation, check if the well is flowing, shut-in the BOP, measure the pressures, adjust the mud weight, and then circulate the kick out of the well as in standard methods. The mass flow together with the flow rate measurements provide a very efficient and fast way of detecting an inflow of gas. Also, the complete removal of the gas from the well is easily determined by the combination of the mass flow and flow rates in and out of the well.
Also the incorporation of early detection of influx/loss devices, which can preemptively result in opening or closing the pressure/flow control device ([0151] 12), as part of the system, will allow pro-active reaction to influx/losses not achieved by state-of the-art systems.
The function of the rotating pressure containment device ([0152] 26) is to allow the drill string (1) to pass through it and rotate, if a rotating drilling activity is carried on. Thus, the drill string (1) is stripped through the rotating pressure containment device; the annulus between the outside of the drill pipe and the inside of the wellbore/casing/riser is closed by this equipment. The rotating pressure containment device (26) can be replaced by a simplified pressure containment device such as the stripper(s) (a type of BOP designed to allow continuous passage of non-jointed pipe) on coiled tubing operations. The return flow of drilling fluid is, therefore, diverted to a closed pipe (27) to the surface treatment package. This surface package should be composed of at least a degasser (13) and shale shaker (4) for solids separation. This way the influxes can be automatically handled.
In a more appropriate configuration, a closed 3-phase separator (liquid, solid and gas) could be installed replacing the degasser ([0153] 13). In this case a fully closed system is achieved. This may be desirable when dealing with hostile fluids or fluids posing environmentally risks.
The central data acquisition and control system ([0154] 18) receives all the signals of different drilling parameters, including but not limited to injection and return flow rates, injection and return mass flow rates, back-pressure at the surface, down-hole pressure, cuttings mass rates, rate of penetration, mud density, rock lithology, and wellbore diameter. It is not necessary to use all these parameters with the drilling method herein proposed.
The central data acquisition and control system ([0155] 18) processes the signals received and looks for any deviation from expected behavior. If a deviation is detected, the central data acquisition and control system (18) activates the flow pressure/flow control device (12) to adjust the back-pressure on the return line (27). This is coupled with a feedback loop to constantly monitor the reaction to each action, as well as the necessary software design, and any necessary decision system including but not limited to databases and fuzzy logic filters to ensure consistent operation.
In spite of the fact that some early-detection means have been described, it should be understood that the present method and system is not limited to the described items. Thus, an influx may be detected by other means including but not limited to downhole temperature effects, downhole hydrocarbon detection, pressure changes, pressure pulses; said system pre-emptively adjusting backpressure on the wellbore based on influx or loss indication before surface system detection. [0156]
The drilling of the well is done with the rotating pressure containment device ([0157] 26) closed against the drill string. If a deviation outside the predicted values of the return flow and mass flow rates is observed, the control system (18) sends a signal either to open the flow, reducing the back-pressure or restricting the flow, increasing the back-pressure.
This deviation may also be a signal from an early detection device. [0158]
The first option (flow opening) is applied in case a fluid loss is detected and the second one (flow restriction), if a fluid gain is observed. The changes in flow are done in steps previously defined steps. These step changes can be adjusted as the well is drilled and the effective pore and fracture pressures are determined. [0159]
The whole drilling operation is continuously monitored so that a switch to a manual control can be implemented, if anything goes wrong. Any adjustments and modifications can also be implemented as the drilling progresses. If at all desired, restoring to the state-of-the-art drilling method is easily done, by not using anymore the rotating pressure containment device ([0160] 26) against the drill string (1), allowing the annulus to be open to the atmosphere again.
A block diagram of the method described in the present invention is shown in FIG. 5. [0161]
In fact, the present system and method implies many variations and modifications within its scope and as such it can be applied to all kinds of wells, onshore as well as offshore, and the equipment location and distribution can vary according to the well, risks, application and restrictions of each case. [0162]
FIG. 6 is a flowchart illustrating the drilling method of the invention in a schematic mode, with the decision-making process that leads to the restoration of the predicted flow as determined by the central data acquisition and control system. [0163]
It has been mentioned before that in the conventional drilling methods the hydrostatic pressure exerted by the mud column is responsible for keeping the reservoir fluids from flowing into the well. This is called a primary safety barrier. All drilling operations should have two safety barriers, the second one usually being the blow-out preventer equipment, which can be closed in case an influx occurs. The drilling method and system herein described introduces for the first time three safety barriers during drilling, these being the drilling fluid, the blow-out preventer equipment, and the rotating pressure containment device. [0164]
In underbalanced drilling (UBD) operations, there are just two barriers, the rotating pressure containment device and the blow-out preventer, since the drilling fluid inside the wellbore must exert a bottomhole pressure smaller than the reservoir pressure to allow production while drilling. [0165]
As noted before, there are three other main methods of closed system drilling, known as underbalanced drilling (UBD), mud-cap drilling, and air drilling. All three methods have restricted operating scenarios applicable to small portions of the wellbore, with mud-cap drilling and air drilling only usable under very specific conditions, whereas the method herein described is applicable to the entire length of the wellbore. [0166]

TABLE 1 below shows the key differences among the traditional drilling system (Conv.), compared with the underbalanced drilling system (UBD) and the present drilling method herein proposed. It can be seen that the key points addressed by the present application are not covered or considered by either the traditional conventional drilling system or by the underbalanced drilling method currently used by the industry.

TABLE 1


Feature	UBD	Conv.	INVENTION

Well closed at all times	Yes	No	Yes
Production of reservoir fluids while	Yes	No	No
drilling
Flow rates measured in and out	Yes	Yes	Yes
Mass flow measured in	No	No	Yes
Mass flow measured out	Yes	No	Yes
Pressure/flow control device on the	Yes	No	Yes
return line
Return flow adjusted automatically	No	No	Yes
according to mass balance
Degasser device on the return line	Yes	No	Yes
Kick detection accurate and fast	N/A	No	Yes
Real time¹kick/loss detection while	No	No	Yes
drilling
Can instantly utilize input from early	N/A	No	Yes
detection of kick/loss
Bottom-hole pressure instantly²adjusted	No	No	Yes
from surface with small action
Three safety barriers while drilling	No	No	Yes
Accurate pore and fracture pressure	No	No	Yes
determination while drilling
Can keep a constant pressure at bottom	No	No	Yes
hole during connections and trips
Immediate control of the well in case of	N/A	No	Yes
kick
Can be used to drill the entire well	No	Yes	Yes
Can be used to drill safely within a very	No	No	Yes
narrow pore/fracture pressure margin

The present method is applicable to the whole wellbore from the first casing string with a BOP connection, and to any type of well (gas, oil or geothermal), and to any environment (land, offshore, deep offshore, ultra-deep offshore). It can be implemented and adopted to any rig or drilling installation that uses the conventional method with very few exceptions and limitations. [0168]
Thus the present method can be called INTELLIGENT SAFE DRILLING, since the response to influx or losses is nearly immediate and so smoothly done that the drilling can go on without any break in the normal course of action, this representing an unusual and unknown feature in the technique. [0169]
Therefore, the present system and method of drilling makes possible: [0170]
i) accurate and fast determination of any difference between the in and out flow, detecting any fluid losses or influx; [0171]
ii) easy and fast control of the influx or losses; [0172]
iii) strong increase of drilling operations safety in challenging environments, such as when drilling in narrow margin between pore and fracture pressures; [0173]
iv) strong increase of drilling operations safety when drilling in locations with pore pressure uncertainty, such as exploration wells; [0174]
v) strong increase of drilling operations safety when drilling in locations with high pore pressure; [0175]
vi) easy switch to underbalanced or conventional drilling modes; [0176]
vii) drilling with minimum overbalance, increasing the productivity of the wells, increasing the rate of penetration and thus reducing the overall drilling time; [0177]
viii) direct determination of both the pore and fracture pressures; [0178]
ix) a large reduction in time and therefore cost spent weighting (increasing density) and cutting back (decreasing density) mud systems; [0179]
x) a large reduction in the cost of wells by reduction in the number of necessary casing strings; [0180]
xi) a significant cost reduction in the cost of wells by significantly reducing or eliminating completely the time spent on the problems of differential sticking, lost circulation; [0181]
xii) significantly reducing the risk of underground blow-outs; [0182]
xiii) a significant reduction of risk to personnel compared to conventional drilling due to the fact that the wellbore is closed at all times, e.g., exposure to sour gas; [0183]
xiv) a significant cost reduction due to lowering quantities of mud lost to formations; [0184]
xv) a significant improvement in productivity of producing horizons by reduction of fluid loss and consequential permeability reduction (damage); [0185]
xvi) a significant improvement in exploration success as fluid invasion due to overweighted mud is limited. Such fluid invasion can mask the presence of hydrocarbons during evaluation by electric logs; [0186]
xv) to drill wells in ultra deep water that are reaching technical limit with conventional state-of-the art method; [0187]
xvi) to economically drill ultra-deep wells onshore and offshore by increasing the reach of casing strings. [0188]

Claims

I claim:

1. A system for drilling a well while injecting a drilling fluid through an injection line of said well and recovering through a return line of said well where the well being drilled is closed at all times comprises a pressure containment device and pressure/flow control device to a wellbore to establish/maintain a back pressure on the well, means to monitor the fluid flow in and out, means to monitor flow of any other material in and out, means to monitor parameters affecting the monitored flow value and means to predict a calculated value of flow out at any given time and to obtain real time information on discrepancy between predicted and monitored flow out and converting to a value for adjusting the pressure/flow control device and restoring the predicted flow value.

2. A system of drilling a well while being drilled with a drill string having a drilling fluid circulated therethrough, while the well is kept closed at all times, wherein the system comprises:

a) a pressure containment device;

b) a pressure/flow control device on the outlet stream;

c) means for measuring mass or volumetric flow and flow rate on the inlet and outlet streams to obtain real time mass or volumetric flow signals;

d) means for measuring mass or volumetric flow and flow rate of any other materials in and out;

f) a central data acquisition and control system programmed with a software that can determine a real time predicted out flow and compare it to the actual out flow estimated from the mass and volumetric flow rate values and other relevant parameters.

3. A system of drilling a well while being drilled with a drill string having a drilling fluid circulated therethrough, while the well is kept closed at all times, wherein said system comprises:

a) a pressure containment device;

b) a pressure/flow control device on the outlet stream;

c) means for measuring mass flow rate on the inlet and outlet streams;

d) means for measuring volumetric flow rate on the inlet and outlet streams;

e) at least one pressure sensor to obtain pressure data;

f) at least one temperature sensor to obtain temperature data;

4. A system according to claim 1 wherein the well is a gas, oil or geothermal well.

5. A system according to claim 3 wherein the at least one pressure sensor is located at the wellhead.

6. A system according to claim 3 wherein the system comprises two pressure sensors.

7. A system according to claim 6, wherein one pressure sensor is at the wellhead and the other one at the bottomhole.

8. A system according to claim 1 wherein the said central data acquisition and control system is provided with a time-based software to allow for lag time between in and out flux.

9. A system according to claims 1 or 8 wherein said software is provided with detection filters and/or processing filters to eliminate/reduce false indications on the received mass and fluid flow data, and any other measured or detected parameters.

10. A system according to claim 1 which comprises three safety barriers, the drilling fluid, the blow-out preventer equipment and the pressure containment device.

11. Method comprising, in relation to the system according to claim 1, the following steps of injecting drilling fluid through said injection line through which said fluid is made to contact said means for monitoring flow and recovering drilling fluid through said return line; collecting any other material at the surface; measuring the flow in and out of the well and collecting flow and flow rate signals; measuring parameters affecting the monitored flow value and means; directing all the collected flow, correction and flow rate signals to the said central data acquisition and control system; monitoring parameters affecting the monitored flow value and means to predict a calculated value of flow out at any given time and to obtain real time information on discrepancy between predicted and monitored flow out and converting to a value for adjusting the pressure/flow control device and restoring the predicted flow value.

12. A method of drilling a well while being drilled with a drill string having a drilling fluid circulated therethrough, while the well is kept closed at all times, said method comprising the steps of:

a) providing a pressure containment device to the wellbore;

d) providing mass flow meters in both injection and return lines;

e) providing flow rate meters in both injection and return lines;

f) providing at least one pressure sensor;

g) providing at least one temperature sensor;

h) injecting drilling fluid through an injection line through which said fluid is made to contact said mass flow meters, said fluid flow meters, and said pressure and temperature sensors, and recovering drilling fluid through a return line;

i) collecting drill cuttings at the surface;

n) the software of the central data acquisition and control system considering, at each time, the predicted flow out of the well;

o) having the actual and predicted out flows compared and checked for any discrepancy;

13. A method of continuous, safe drilling of a well being drilled with a drill string having a drilling fluid circulated therethrough, while the well is kept closed at all times, said method comprising the steps of:

a) providing a pressure containment device to the wellbore;

d) providing mass flow meters in both injection and return lines;

e) providing flow rate meters in both injection and return lines;

f) providing at least one pressure sensor to measure pressure;

g) providing at least one temperature sensor to measure temperature;

h) injecting drilling fluid through an injection line through which said fluid is made to contact said mass flow meters, said fluid flow meters and said pressure and temperature sensors, and recovering drilling fluid through return line;

i) collecting drill cuttings at the surface;

j)measuring the mass flow in and out of the well and collecting mass flow signals;

p) in case of a discrepancy, having a signal sent by the central data acquisition and control system to adjust the pressure/flow control device and restore the predicted out flow rate without interruption of the drilling operation.

14. A method according to claims 12 or 13 wherein the well is a gas, oil or geothermal well.

15. A method according to claims 12 or 13 wherein the at least one pressure sensor is located at the wellhead.

16. A method according to claims 12 or 13 wherein the method comprises two pressure sensors.

17. A method according to claim 16, wherein one pressure sensor is at the wellhead and the other one is at the bottomhole.

18. A method according to claims 12 or 13 wherein the Equivalent Circulating Density of the well being drilled is adjusted by closing or opening the pressure/flow control device.

19. A method according to claims 12 or 13 wherein the discrepancy between actual and predicted out flows is a fluid loss and the adjustment of the pressure/flow control device comprises opening said device to the extent required to counteract fluid loss and reduce backpressure.

20. A method according to claims 12 or 13 wherein the discrepancy between actual and predicted out flows is a fluid gain and the adjustment of the pressure/flow control device comprises closing said device to the extent required to counteract fluid gain and increase backpressure.

21. A method according to claims 12 or 13 wherein the predicted ideal value for the outflow is based on calculations taking into account among others rate of penetration, rock and drilling fluid density, well diameter, in and out flow rates, cuttings return rate, bottomhole and wellhead pressures and temperatures.

22. A method according to claims 12 or 13 wherein the software provided to the central data acquisition and control system receives as input any early detection parameters to ascertain that an influx/loss has occurred.

23. A method according to claims 12 or 13 wherein the mass flow metering comprises any subcomponents designed to improve accuracy of the measurement.

24. A method according to claim 23, wherein the subcomponents comprise measuring the mass flux of cuttings being produced at the shakers and mass outflow of gas from the said degasser.

25. A method according to claims 12 or 13 wherein means are provided to pressurize the well bore through the annulus, independently of the current fluid injection path.

26. A method according to claim 23, wherein the subcomponents comprise measuring the mass flow and fluid flow into the well bore through the annulus, independently of the current fluid injection path.

27. A method for the real time determination of the fracture pressure of a well being drilled with a drill string and drilling fluid circulated therethrough, while the well is kept closed at all times, said method comprising the steps of:

a) providing a pressure sensor at the bottom of the drill string;

b) having fluid and mass flow data generated collected and directed to a central data acquisition and control device that sets an expected value for fluid and mass flow;

c) the said central data acquisition and control device continuously comparing the said expected fluid and mass flow to the actual fluid and mass flow;

d) in case of a discrepancy between the expected and actual value, the said central data acquisition and control device activating a pressure/flow control device;

e) the detected discrepancy being a fluid loss, the value of the fracture pressure being obtained from a direct reading of the bottomhole pressure.

28. A method for the real-time determination of the pore pressure of a well being drilled with a drill string and drilling fluid circulated therethrough, while the well is kept closed at all times, said method comprising the steps of:

a) providing a pressure sensor at the bottom of the drill string;

e) the detected discrepancy being an influx, the value of the pore pressure being obtained from a direct reading of the bottomhole pressure provided by the said pressure sensor.