DE102010006141A1 - DDS for deep geothermal energy - Google Patents

Abstract

Process for exploration, development and production of geothermal energy through the inflow of water via cased boreholes in deep geological formations (DDS: Deep Directivity System; Polarized Reservoir Method) with the following steps: - Search and exploration of an ideal reservoir (2, 2A, 2B, 2C) with high formation temperature - drilling a sub-vertical or deviated production well into the reservoir as specified in 2, 2A, 2B and 2C - log measurements in the well and reservoir formation and testing for porosity, permeability and geomechanical parameters - eventual test in preparation for the frac- Method or other stimulation method for generating a storage inflow volume (collector) when insufficient permeability is present, as specified in FIGS. 2, 2A, 2B, 2C, 3X, 3X, 10, 11, 18, 19, 20, 21 and 22 - Drilling of a sub-vertical main injection well (DW1) with ISP (starting point of the injection well) far from the PSP (starting point of the prod uktionsbohrung) removed, either to the sidetrack or to the reservoir vertical depth (3X, 3Z) - log measurements and ...

Description

FIELD OF THE INVENTION

This invention describes an end product for the extraction of heat from the deep earth.

The method belongs to geothermal exploration and extraction methods.

STATE OF THE ART

• 1. Hot Dry Rock
• 2. Hydrothermale Geothermie

To date, geothermal energy has consisted of two main methods:

• 1. Hot Dry Rock
• 2. Hydrothermal geothermal energy

HOT DRY ROCK

The method uses the fractures or permeability in the deep geological formations.

Water is pumped into these clefts. The water flows through the permeability and is heated by heat conduction.

Due to the inflow, the water transports the heat by conduction.

There are usually two holes drilled.

An injection well and a production well.

The water is pumped through pumps in the injection well and will flow down to the bottom of the well.

There it continues to flow through the permeability of a given layer for a few hundred meters or even a few kilometers to the production well.

From the bottom of the production well, the water is pumped upwards with "downhole pumps".

At the surface, the water will flow through heat exchangers and then, again for a new cycle, will be pumped into the injection well.

The heat exchangers operate a power plant or a heating center for a municipality or a district.

HYDROTHERMAL GEOTHERMIA

Hydrothermal geothermal uses existing heat activators contained in the porosity / permeability system of deeper formations.

A production well is drilled to a suitable target of the Acquicer.

Another injection well is usually drilled 2 to 3 kilometers from another target.

The aim of the injection well is to let water flow out of the heat exchanger and reinject it into the formation.

The heat exchangers on the surface operate a power plant or a heating center for a municipality or a district.

Both methods have significant limitations and risks.

The current methods of seismic exploration are very expensive and still have too low resolution. Often too low to accurately pinpoint the trapping and permeability directivity. Such methods are also very expensive for the project risk.

In general, a cheap 3D seismic costs more than 2 million EU.

The results are often an uncontrolled "waterflooding" where the water flow through the formation takes uncontrolled paths and thus can not achieve the desired directivity.

In particular, azimuthal etherogeneity can not be identified without modern multi-component seismics and petrophysical measurements.

Also Fracverfahren that should produce an artificial Kluftspermeabilität are partially uncontrollable, especially when the distance increases.

Many projects have failed because of these problems.

PRESENTATION OF THE INVENTION

Deep Directivity Systems for geothermal energy (DDS).

The innovation described here makes it possible to avoid the risk of water flooding by directing the water (or steam) directly through the "thermal" directional drilling Production reservoir and to the production well.

• 1. Phase 1 Planungsphase. – Exploration und Identifizierung eines geeigneten Reservoirs oder Wasser Speicher und Zuflusssystem. – Berechnung des Produktionstarget und des Bohrlochverlaufs. – Exploration und Identifizierung eines geeigneten Punkts für die Injektionsbohrung. – Berechnung des Injektionstarget und des Bohrlochverlaufs.
• 2. Bohrung der Produktionsbohrung in einem geeigneten Target in das Reservoir, Verrohrung und Testen des Reservoirs.
• 3. Bohrung der Injektionsbohrung in einem geeigneten Landepunkt (Target) in das Reservoir, Verrohrung und Testen des Reservoirs.
• 4. Vorbereitung des Reservoirs durch Stimulations- und Frac-Verfahren.
• 5. Produktionstest

The realization of a DDS system is divided into 3 project phases.

• 1st phase 1 planning phase. - Exploration and identification of a suitable reservoir or water storage and inflow system. - Calculation of the production target and the course of the borehole. - Exploration and identification of a suitable point for the injection well. - Calculation of the injection target and the course of the borehole.
• 2. Drilling the production well in a suitable target into the reservoir, piping and testing the reservoir.
• 3. Drill the injection well at a suitable landing point (target) into the reservoir, piping and testing the reservoir.
• 4. Preparation of the reservoir by stimulation and frac methods.
• 5th production test

Directivity Wells (DW)

The drilling structure

Each hole is geometrically divided into 2 parts.

The main hole or directivity hole 1 (DW1) and the sub hole or directivity hole 2 (DW2).

The main bore is usually the subvertical phase (larger diameter) from the surface to below the deflection point (sidetrack point).

The sub-bore is usually the subhorizontal phase of smaller diameter exiting the main bore at the sidetrack point.

DW2 can either be conventional diameter "Conventional Hole": 13 to 7 inches in diameter or thinner diameter 7 to 2.5 "Slim-Hole Drillpipe" (SHDP) or "Coiled Tubing" (CT).

The use of multilateral wells in HD and / or hydrothermal geothermal energy is one of the innovations described below, in which different points of the reservoir (target) can be reached and produced simultaneously.

Frac operations

Particularly critical is the phase of preparation of the reservoir for the inflow of water.

This is done either by Frac or by stimulation (in carbonates, acidification stimulation) if the natural permeability is insufficient.

As an innovation, a new frac method for geothermal operations is presented here to bring production to maximum efficiency.

The Time Synchronized Bipolar, Tripolar, or Multipolar Frac (Simultaneous Bipolar Frac) Method.

With this method one can (in the case of a bipolar frac method) reorient the second major stress sigma 2 in the direction of the dipole. In certain situations, the dipole stress can overtake the first major stress Sigma 1 and develop a horizontal gap. (Low Tepth, Higher Pore Pressure, Multipolar Frac Method).

The stress dipole consists of two poles (Pole 1 and Pole 2) in two adjacent piping (Pole 1 in Piping 1, Pole 2 in Piping 2).

The poles are the source of the active stress field (Sigma D).

The poles must be as close as possible to each other (ideally opposite each other), so that a connecting line between the poles as possible a 90 degree angle to the casing would result.

This connection line should also be as parallel as possible to Sigma 2.

If this is not the case, the effect of Sigma D will turn the sigma 2 stress field in its direction.

In practice, the poles consist of perforations in the casing. These allow high pressure water to flow from the casing into the formation.

The stress field is generated in the high-pressure liquid (slurry or gel) simultaneously from the two poles (P1, P2) of the two different drill sections is pumped.

The time-programmed pressure control initiates and controls the frac process.

The poles (P1, P2) correspond to the perforations of the piping. The relative positioning of the perforations is therefore very important ( 18 ). They should lie in the maximum symmetry axis of the frac profile, if possible parallel to the sigma 2 (in the case of homogeneous / isotropic formations).

The two Frac main stress directions are in the opposite direction and are in the "Frac Petrophysical Streamlines".

As "Frac Petrophysical Streamlines" here is a not necessarily straight line (or plane) defines the two poles touches and consists of points that correspond to the lowest resistance in the Frac process.

This line, located at the Frac level, is calculated by geomechanical analysis and is a function of lithostatic stress tore, tectonic stress tore, frac-induced stress tore, and petrophysical-geomechanical heterogeneity.

An example is points along the same Sigma 2 stress vector line in a homogeneous-isotropic medium. In the mechanical heterogeneity, the spatial distribution of the mechanical parameters also comes into play.

Shear Modulus, Poisson Number, Klc (Fracture Toughness).

Often this space is contained in a layer or formation. ( 10 to 21 and 6A illustrates such methods).

Frac processes are performed by "perforating" the two sub-parallel adjacent casings.

The perforation must also have a directivity. She should be in the "Pole Streamline".

Before frac surgery, detailed tests and studies are necessary.

The elastic parameters, stress profiles and stress tensors should be studied closely.

Normally, the fractures are subvertical and perpendicular to sigma 3 (parallel to sigma 2).

In certain situations one can try to create horizontal scents.

This is not easy and is very dependent on the overlay pressure Sigma 1, but could be achieved at the layer boundaries with special "gels".

The method can be extended to three or more poles. Time-Synchronized Tripolar Frac (Simultaneous-Tripolar Frac-Method) etc. ( 22 )

The tripolar or multipolar frac method presented here can achieve the goal of the horizontal frac process. ( 18 ) and ( 22 ).

If a frac operation is applied to the bed boundary, the area for loss must first be tested.

Height losses without pressure limitation are unfavorable for the realization of the project.

Reservoir storage and streamline volume

• 1. Gravitationscontainment-Synclinale-Kollektor (Gravity Containment/Syncline Collector) (2A)
• 2. Stresscontainment Kollektor (Stresscontainment Collector) (2B)
• 3. Homogen/Isotrop Kollektor (Homogeneous/Isotropic Collector) (2C)

• 1. Der Gravitationscontainment-Synclinale-Kollektor ist eine synclinale Struktur einer impermeablen Schicht (B) überlagert bei Formationen (A) mit höherer relativer Permeabilität.
• 2. Der Stresscontainment Kollektor besteht aus einer Schicht/Formation mit niedrigerem Stress-Profil als die oberen und unteren Schichten oder Formationen.
• 3. Der Homogen/Isotrop Kollektor besteht aus einer dichten kompakten Formation, wo einen inneres Speichervolumen durch Frac-Verfahren erzeugt werden kann. Homogen und Isotrop ist nur ein idealisierter Name.

Here are presented 3 types.

• 1. Gravity Containment-Synclinale-Collector (Gravity Containment / Syncline Collector) ( 2A )
• 2. Stress Containment Collector ( 2 B )
• 3. Homogeneous / Isotropic Collector (Homogeneous / Isotropic Collector) ( 2C )

• 1. The Gravitation Containment Synclinale Collector is a synclinal structure of an impermeable layer (B) superimposed on higher relative permeability formations (A).
• 2. The stress containment collector consists of a layer / formation with a lower stress profile than the upper and lower layers or formations.
• 3. The Homogeneous / Isotropic Collector consists of a dense compact formation, where an internal storage volume can be generated by Frac processes. Homogeneous and isotropic is just an idealized name.

In geological reality such conditions are rarely found.

Mixed solutions are also possible. The boundary between two layers with different geomechanical parameters are also possible project spaces.

The feasibility can only be determined by geomechanical analysis.

In case of water loss different types of LCM (Lost Circulation Material) can be used.

Geometric configuration

• A. Polarisiertes Reservoir Projekt
• B. Mittel Reservoir Projekt

Here are two project types presented:

• A. Polarized Reservoir Project
• B. Medium Reservoir Project

POLARIZED RESERVOIR MODEL

The geometric configuration of the polarized model, provides that the production bore start point (Spud point) (PSP) is vertical or slightly deflected over the reservoir.

• 1. Geophysikalische Messungen (Seismik, Petrophysik, Gravimetrie, Magnetotellurik usw.), Projektplan und Target-Definition.
• 2. Bohrung der Hauptproduktionsbohrung bis zum Reservoir Target. Messungen, Verrohrung und Tests.
• 3. Bohrung des Hauptinjektionsbohrung bis zum Reservoir (Vertikal Phase und Horizontal Phase) oder Bohrung des Hauptinjektionsbohrung und dann Bohrung eines „Multilateral” subhorizontalen Systems von Nebenbohrungen (mindestens 3), Abgelenkt (1) aus der Sohle der Hauptbohrung. Die Nebenbohrungen sind subhorizontal. Zuerst treten sie aus den Ablenkungspunkten aus und konvergieren in dem Reservoir (Fan System) (4)
• 4. Messungen, Verrohrung, Tests und Frac oder Stimulation-Verfahren.
• 5. Inbetriebnahme des Zirkulationssystem und Testes.

The spud point of the injection well (ISP) is a few hundred meters to kilometers away from the PSP. ( 3 . 4 ) Phases:

• 1. Geophysical measurements (seismics, petrophysics, gravimetry, magnetotellurics, etc.), project plan and target definition.
• 2. Drill the main production hole to the Reservoir Target. Measurements, piping and tests.
• 3. Drilling of the main injection well to the reservoir (vertical phase and horizontal phase) or drilling of the main injection well and then drilling of a "multilateral" subhorizontal system of secondary wells (at least 3), deflected ( 1 ) from the bottom of the main bore. The side holes are subhorizontal. First, they exit the deflection points and converge in the reservoir (Fan System) ( 4 )
• 4. Measurements, Piping, Tests and Frac or Stimulation Procedures.
• 5. Commissioning of the circulation system and test.

MEDIUM RESERVOIR MODEL

The geometric configuration of the central reservoir project, provides
that both PSP and ISP are not vertically above the reservoir. You can have a few hundred meters to a few kilometers distance to the vertical of the reservoir. PSP and ISP may be symmetrical or asymmetric with respect to the reservoir. ( 5 and 6 to 6G )

phases:

• 1. Geophysical measurements (seismics, petrophysics, gravimetry, magnetotellurics, etc.), project plan and target definition.
• 2. Drilling of the main production well down to the reservoir (target reservoir) (vertical phase and horizontal phase) or drilling of the main production well and then drilling of a "multilateral" subhorizontal system of secondary wells (at least 3), deflected ( 1 ) from the bottom of the main bore. The side holes are subhorizontal. First, they exit from the deflection points and then converge in the reservoir (Fan System) ( 4 )
• 3. Measurements, piping and test.
• 4. Drilling the main injection well to the reservoir (vertical phase and horizontal phase) or drilling the main injection well and then drilling a "multilateral" subhorizontal system of sub-wells (at least 3), deflected ( 1 ) from the bottom of the main bore. The side holes are subhorizontal. First, they exit from the deflection points and then converge in the reservoir (Fan System) ( 4 )
• 5. Measurements, Piping, Tests and Frac or Stimulation Procedures.
• 6. Commissioning of the circulation system and test.

MULTILATERAL TECHNOLOGY FOR HYDROTHERMAL AQUIFERE

Especially for hydrothermal or hydrogeothermal geothermal energy, Multilateral technology would increase efficiency significantly.

Applications of Multilateral Technology are presented here as an innovation for simultaneous hot water (steam) production from multiple aquifers. ( 8th )

Especially in karstic carbonates, this technology will increase the flow rate. With this method, several "sidetrack holes" are deflected out of the main hole and lead away to reach different reservoirs.

BRIEF DESCRIPTION OF THE DRAWINGS

1
Shows a sidetrack mechanism with coiled tubing (CT) or slime-hole drill string or "slimhole drill pipe" (SHDP).

The main hole or DW1 is vertical.

The subbore or DW2 is a directional bore that first drills the tubing ( 1 ) (Sidetrack) and then subhorizontally diverges to the target.

2
Shows an example of how a production well with the sole can be positioned in an impermeable thick layer ( 2 ) is the reservoir formation.

2A
A schematic view of a Synclinale Gravitation Containment Collector.

2 B
A schematic example of a pressure containment collector.

2C
A schematic example of a homogeneous / isotropic collector

3X
A vertical section (projection) of a polarized reservoir project with distanced PSP and ISP.

3Y
A horizontal section of a polarized reservoir project with distanced PSP and ISP and "Fan System" DW2.

3A
A schematic example in vertical section of a double cross-polarized, feedback loop, reservoir model (sub-horizontal section conventional diameter)

3B
A schematic example in vertical section of a double cross-polarized, feedback loop, reservoir model with direct feedback circulation in (A). (sub-horizontal section conventional diameter)

3C
A schematic example in vertical section of a double cross-polarized, feedback loop, reservoir model (subhorizontal section conventional diameter). Here it is better shown how the two subhorizontal sections can have different geometries.

3D
A schematic example in vertical section of a triple cross-polarized, feedback loop, reservoir model (subhorizontal drill section as conventional diameter).

The feed heads (B) or / and (C) can also direct flow feed back as in 3B to have.

By the same method, there could also be quadruple or multiple cross-polarized feedback projects, with four or a multiple of 2 holes given.

3And
A schematic example in vertical section of a triple cross-polarized, feedback loop, reservoir model (subhorizontal DW2 drill section are deflected "slim-hole" or CT bores).

The conveying heads (B) or / and (C) can also be used in direct feedback circulation as in 3B be.

By the same method, there could also be quadruple or multiple cross-polarized feedback projects, with four or a multiple of 2 holes given.

3E
A schematic example in a 3D view of a triple cross-polarized, feedback loop, reservoir model as in 3D ,

3F
A schematic example in vertical section of a double cross-polarized, feedback loop, reservoir model (subhorizontal DW2 drill sections are deflected "slim-hole" or CT bores).

A delivery head (A) or (B) can also be used in direct feedback circulation as in 3B be.

3G
A schematic example in horizontal section of a double cross-polarized, feedback loop, reservoir model as in 3F , (Subhorizontal DW2 drill sections are deflected "slim-hole" or CT holes).

A delivery head (A) or (B) can also be used in direct feedback circulation as in 3B be.

3H
A schematic example in horizontal section of a triple cross-polarized, feedback loop, reservoir model (subhorizontal DW2 drill sections are deflected "slim-hole" or CT bores).

The conveying heads (B) or / and (C) can also be used in direct feedback circulation as in 3B be.

Following this method, there could also be quadruple or multiple cross-polarized feedback projects, with four or a multiple of 2 holes.

3i
A schematic example in vertical section of a variant of 3B Here, the point of re-injection on the surface with solar collectors ( 9 ). This is a good solution for regions of low latitude and depending on the flowing water temperature.

3M
A schematic example in vertical section of a triple cross-polarized, feedback loop, Reservoir model (subhorizontal drill section as conventional diameter).

The delivery heads (B) or / and (C) may also have direct flow feedback such as (B).

This variant shows that multiple producers and multiple injectors can land on a reservoir. In this case, the reservoir ( 1 ) the main reservoir. The others are the ones next to Reservoirs.

(A) and (C) are heat exchangers, (B) a flow feed back.

The horizontal holes can be replaced by several "Slim-Hole" DP or CT holes as in 3And ,

By the same method, there could also be quadruple or multiple cross-polarized feedback projects, with four or a multiple of 2 holes given.

4
A Three-Dimensional Scheme of a Polarized Reservoir Project where the deflection points emerge from a DW1 that lies above the plane p.

5
A schematic example in vertical section of a central reservoir project with distanced PSP and ISP.

6
A schematic example in the horizontal section of a Mittel Reservoir project with distanced PSP and ISP and "Fan System" DW2.

6A
A schematic example of a possible horizontal waterflooding variant in a middle reservoir project like in 6 ,

6B
A schematic example in vertical section of a medium reservoir project with near PSP and ISP and several "slim-holes" or CT injector holes DW2 and well DW2.

6C
A schematic example in vertical section of a medium reservoir project with near PSP and ISP and several injector wells DW2 and well DW2. (Eccentric variant).

6D
A schematic example in vertical section of a medium reservoir project with near PSP and ISP, with several injector bores DW2 and only one conventional diameter production well DW1 + DW2. Eccentric variant.

6E
A schematic example in vertical section of a medium reservoir project with near PSP and ISP, with several injector bores DW2 and only one conventional diameter production well DW1 + DW2. Central / Subcentral variant.

6F
A schematic example in the horizontal section of a medium reservoir project with near PSP and ISP, with several injector wells DW2 and only one production well DW1 + DW2. Eccentric variant. (Equal. 6D ) Symmetrical injector DW2 arrangement.

6G
A schematic example in horizontal section of a medium reservoir project with near PSP and ISP, with several injector wells DW2 and only one production well DW1 + DW2. Eccentric variant. (Equal. 6D )

Asymmetrical injector DW2 arrangement.

7
A schematic example in the vertical section of a DW2 deflected from a DW1 (sidetrack) and drilled in the direction of a target.

This is a method of producing hot water or steam.

The innovation is the application of "Multilateral Technology" for hydrothermal or hydrogeothermal geothermal applications where hot water is present in the formation and only needs to be pumped to the surface. When creating multi-lateral wells, multiple targets / reservoirs can be achieved simultaneously and the overall flow rate / production can be increased.

After exchanging the heat in the heat exchanger, the water must be pumped back into the deep formations. This can be done through a single hole.

However, the reinjected water must land far away from the "Multilateral Wells" bottom.

8th
A schematic example in the vertical section of a "multilateral drilling system".

9
A schematic example in a vertical section of a flow restrictor for pressure equalization and flow rate compensation and regulation in the slim-hole or CT DW2.

10
A schematic example in the horizontal section of a time-synchronized bipolar frac process between DW2 injector end-hole and production well and between sub-parallel DW2 injectors

At the bottom of the hole, the formation is fractured with high-density mud
(intensive LOT / FIT).

Between pipes, the "frac" takes place in the multipolar mechanism using a conventional frac process.

11
A schematic example in the horizontal section of time-synchronized bipolar frac processes between DW2 Injector End Holes and Production Wells and between sub-parallel DW2 injectors.

Between Borehole Piping and Injector DW2 Sole is Fitted with Conventional Frac Bipolar Mechanisms.

Between pipes, the "frac" takes place in the multipolar mechanism with a conventional frac process.

12
A schematic example in horizontal or vertical section of time-synchronized bipolar frac method between "slim-hole" or CT injection and DW2 production in the storage and inflow volume. Eccentric central reservoir with many injector and DW2 production.

13
A schematic example in horizontal or vertical section of time-synchronized bipolar frac process between sub-parallel "slim-hole" or CT injector DW and conventional DW2 production in the store and inflow volume through perforations on the side of the casing.

Eccentric central reservoir with many injectors DW2 and a DW2 production.

14
A schematic example in horizontal or vertical section of time-synchronized bipolar or multipolar frac processes between "slim-hole" or CT injectors and DW2 production into the storage and inflow volume, through the DW2 drilling well.

Central central reservoir with many injector and DW2 production.

15
A schematic example in horizontal or vertical section of time-synchronized bipolar or multipolar frac processes between "slim-hole" or CT injectors and a conventional-diameter-production DW2 in the storage and inflow volume through the DW2 drilling well.

Central medium reservoir with many injectors and a producer DW2.

16
A variant of 13 ,

The "slim-hole" or CT DW2 are not subparallel.

17
A schematic example in the horizontal or vertical section of time-synchronized bipolar or multipolar frac procedures between "slim-hole" or CT injectors and a conventional-diameter DW2 production in the reservoir and inflow volume through the injectors DW2 and insole lateral Perforations of the production well.

Eccentric central reservoir with many injectors and a production well DW2.

The relative positioning of the DW2 can be changed here and also in the upper figures if necessary

18
A schematic example in a three-dimensional perspective of the positioning of the lateral perforations in adjacent casings for the realization of the Frac process.

The perforations are theoretically in the connecting line between the coupled poles 1 and 2 poles.

The water circulation takes place after commissioning through the formation from one piping to the other.

19E
in a schematic example in a three-dimensional perspective in a stress containment layer. The drawing shows how vertical fractures (A) claim to propagate in a vertical plane between a horizontal DW2 and the other.

20
A schematic example of the Simultaneous Bipolar Fracmethod (Frac) where the frac operation on the wellbore of the production well consists of extended leak-off test with high density mud. At the injector DW2 sole, the Frac process is a conventional high pressure water frac process.

The pressure-time diagram illustrates the pressure time course, which should be similar in all poles.

The pressure should be increased simultaneously, for example in (A) and (B) in the "plateaus" T1. T2, T3, the pressure should be equalized and then increased to fast up to the break point.

21
A schematic example of the Simultaneous Bipolar Fracmethod (Frac) where both the producer well Wells and the Injector DW2 outsole have the conventional high pressure water frac frac operation.

The diagram Pressure-Time illustrates the pressure time course which should be similar in all poles.

The pressure should be increased simultaneously, for example in (A) and (B) in the "plateaus" T1. T2, T3, the pressure should be leveled and then increased to fast to break point.

21
A schematic example of a time-synchronized tripolar frac method (Simultaneous-Tripolar Fracmethod).

This is an example of how a "fracture" can be created between three subcomplete poles at the final stage of an injector bore.

WAYS FOR CARRYING OUT THE INVENTION

• – Tiefe Direktivitätssysteme (Deep Directivity Systems DDS)
• – Multilaterale Bohrtechnologie in der Geothermie
• – Das Zeitsynchronisierte-Bipolare Frac-Verfahren

The following figures are schematic descriptions to explain these new methods of geothermal exploration and production.

• - Deep Directivity Systems (DDS)
• - Multilateral drilling technology in geothermal energy
• The Time Synchronized Bipolar Frac Method

In this description, each element in an image is referenced by a corresponding number or letter.

1
Shows a sidetrack mechanism with coiled tubing (CT) or slime-hole drill pipe (DP).

The main bore or Directivity Well 1 (DW1) is subvertical.

The main well is also called pilot hole because it also serves as the primary formation evaluation by petrophysical measurements and tests.

The sub hole or Directivity Well 2 (DW2) ( 3 ) is a directional bore the first the piping ( 2 ) drills ( 1 ) and then subhorizontally deviates to the target.

The DW2 drilled hole is drilled into the reservoir with a MWD navigation system in a sub-horizontal direction.

Anti-collision programs should also be used with the directional drilling program to avoid collisions with other DW2s or with production drilling.

Before the navigation target is determined, the inflow geometry and frac program must be scheduled.

The configuration and positioning of the injector and production target in the reservoir and ultimately the entire drilling project will be a function of structural heterogeneity.

Injector and production target can also be several hundred meters apart.

Polarized reservoir model

PHASE 1. PLANNING AND IMPLEMENTATION OF PRODUCTION DRILLING

First, innovative solutions for the polarized model are described here. In 2 becomes an example like a production well ( 1 ) can be positioned with the sole in an impermeable thick layer.

In the beginning, a reservoir formation ( 2 ) with the structural and geomechanical / petrophysical properties of the three reservoir models 2A . 2 B . 2C , or a mixed model searched.

Immediately after drilling the production well, the formation is tested and log-analyzed to determine reservoir properties and schedule pacing / frac operations.

2 can be as an example of a mixed reservoir between 2A and 2 B be considered. The layers (A) and (B) are impermeable. ( 2 ) is the reservoir layer with lower stress profile, usually with higher relative permeability.

The production hole is drilled a few meters into the impermeable layer. If necessary, you can immediately after the tubing of the production well through the perforations ( 4 ) in (B) create an artificial synclinal structure. The Frac influence will move up in ( 2 ) and an artificial storage inflow volume ( 3 ) produce.

This storage volume is needed as a collector for the injection water. Alternatively, once the well has been completed, the DW2 Injector can be used to generate the reservoir inflow volume with bipolar / multipolar, time-syncronized Frac methods to achieve more efficient permeability.

Underwater pumps are mounted at the bottom of the production well to pump the hot water up into the heat exchanger.

2A
Shows a schematic view of a Synclinale "Gravitation Containment Collector". Here, the syncline structure acts as a "basin" (A) for the injected water of the DW2 injector (FIG. 2 ). The natural permeability in (A) must be higher than in (B) and (C) but not too high so that no unacceptable pressure losses occur. (A) must therefore be hydraulically tested to obtain accurate near and far field permeability data.

If in (A) the natural permeability is too low, the permeability should be increased with Frac methods.

(B) must be impermeable. If necessary, frac operations can be planned and performed in (B) below the bottom of the well to increase the storage volume. The water inflow from the injector DW2 in the direction of the wellbore ( 1 ) is in ( 3 ) is displayed.

2 B
A schematic example of a stress / pressure containment collector.

The goal in this reservoir model is to create a finite storage and inflow volume by frac operations when the stress profile in (B) is lower than in (A) and (C). The injector ( 2 ) must be positioned as drawn around the inflow in the direction of the production well ( 1 ) to maximize.

2C
A schematic example of a homogenous / isotropic collector.

The formation (A) is a thick, massive and impermeable formation. The storage and inflow volume (B) can be generated either by Frac operations or by stimulation (acidification in carbonates).

Acidification would be advisable only in compact carbonates and not in aerated or karstic carbonates to avoid water loss.

The injector ( 2 ) must be positioned as shown, in order to control the inflow towards the production well ( 1 ) and must flow into the storage / inflow collector (B).

Underwater pumps ( 3 ) will pump the water into the reservoir (B) up into the thermal exchanger.

PHASE 2. PLANNING AND DRILLING THE INJECTION SYSTEM

After the production well has been tested and piped, the phase begins 2 for the preparation of the injection wells DW1, DW2.

• 1. Kontinuierlich (3Z) indem die Bohrung zuerst Vertikal gebohrt wird (1) und dann in einer Horizontalrichtung (2) bis zum Target (3) gesteuert wird. (Die Phase DW1 ist die Subhorizontalphase (1), die Phase Kick-off ist die Steuerungsphase und die Phase DW2 ist die Subvertikal Phase) (2), oder
• 2. Abgelenkt (Sidetracked). (3X). In diesen Verfahren wird zuerst ein Subvertikalbohrung (Pilot-hole) (1) bis zur Sidetrackpunkt (3) oder bis zur Reservoirteufe (6) gebohrt und anschließend wird

mit „Slim-Hole” DP (Drill Pipe) oder CT (Coiled Tubing) (3) die Pilotbohrung DW1 (1) abgelenkt (3) und in subhorizontaler (4) Richtung bis zur Targetarea (7) gebohrt.The injection hole is either:

• 1. Continuously ( 3Z ) by first drilling the hole vertically ( 1 ) and then in a horizontal direction ( 2 ) to the target ( 3 ) is controlled. (The phase DW1 is the subhorizontal phase ( 1 ), the phase kick-off is the control phase and the phase DW2 is the sub-vertical phase) ( 2 ), or
• 2. Distracted (sidetracked). ( 3X ). In these methods, first a sub-vertical hole (pilot hole) ( 1 ) to the sidetrack point ( 3 ) or until the reservoir level ( 6 ) and then drilled

with "Slim Hole" DP (Drill Pipe) or CT (Coiled Tubing) ( 3 ) the pilot hole DW1 ( 1 ) distracted ( 3 ) and subhorizontal ( 4 ) Direction to the target area ( 7 ) drilled.

3X
A vertical section (projection) of a polarized reservoir project with distant PSP and ISP, where the DW2 Slim-Hole is DP or CT. In the "horizontal phase" the piping in permeable "lung areas" may be perforated ( 4 ), but only if these areas are perfectly hermetic ("pressure containment") in order to make the thermal exchange with the formation matrix more efficient through convection. The risk may be loss of water, so the formation should be on this point be tested thoroughly before perforations are performed.

A "lung area" ( 5 ) is a closed permeable storage inflow volume, with impermeable boundaries and thus without water loss.

While drilling the DW2 injector, connectivity to the collector ( 7 ) are constantly tested by tracers.

If hydraulic connectivity and pressure containment are optimal, DW2's drilling history can be adjusted and the drilling system tested for final commissioning.
("Hydraulic pressure containment" means zero water loss in the entire circulation).

3X is a representation of a vertical section (projection) of a polarized reservoir project with superficial circulation feedback between ( 2 ) and ( 1 ).

3Y
Is a schematic example of a horizontal section of a polarized reservoir project with distanced PSP and ISP and "Fan System" DW2 like 3X ,

Here is shown how the DW2 ( 3 ) ( 4 ) after the injector sidetrack point, in a "fan system" to optimally utilize the thermal capacity of the formation, and as in the storage inflow volume (FIG. 5 ) the production wells ( 3 u. 4 ) land. Arrows indicate the inflow of water.

3Z
Shows a vertical section (projection) of a polarized reservoir project with distanced PSP and ISP with continuous drilling profile and superficial inflow feed back from thermal exchanger (A) to thermal exchanger (B).

This model has a low thermal efficiency.

To optimize the thermal efficiency, the main innovation presented here is a variant of the upper model with a deep circulation feedback loop.

The Double, Cross-Polarized Reservoir Model with Deep Circulation Feedback Loop ( 3A )

3A
Double Cross-Polarized Reservoir Model with Deep Circulation Feedback. Here is a schematic example of a project in vertical section with continuous holes from DW1 to DW2 shown.

The arrows indicate the direction of water circulation, from reservoir ( 3 ) to reservoir ( 7 ) through the thermal exchangers (A) and (B).

• (3) Reservoir-Speicher-Zufluss-Volumen 1
• (1) Förderbohrung 1
• (A) Thermaltauscher
• (2) Injektor DW1
• (4) Injektor DW2
• (7) Reservoir-Speicher-Zufluss-Volumen 2
• (6) Förderbohrung 2
• (B) Thermaltauscher
• (8) Injektor DW1
• (5) Injektor DW2

The main components of this project in circulation sequence are:

• ( 3 ) Reservoir storage inflow volume 1
• ( 1 ) Production well 1
• (A) Thermal exchanger
• ( 2 ) Injector DW1
• ( 4 ) Injector DW2
• ( 7 ) Reservoir storage inflow volume 2
• ( 6 ) Production well 2
• (B) Thermal exchanger
• ( 8th ) Injector DW1
• ( 5 ) Injector DW2

3B
Here is the same project as in 3A represented with a single variant. Point (A) is a closed surface circulation feed-back loop.

Here, the water will not flow through heat exchangers, but directly into the reservoir ( 3 reinjected. The thermal efficiency is thus increased again. The water circulation takes place as in 3A with the same components.

3C
Here is the same scheme as in 3A repeatedly with the aim of showing how the horizontal components ( 4 ) or ( 5 ) or the vertical components ( 1 ) 2 ) 8th ) 6 ) can be planned with different directions.

The project scheme can be further extended to variants with higher thermal efficiency.

An example is the triple cross-polarized, feedback loop, reservoir model

3D
A schematic example in vertical section of a reservoir model with triple, cross-polarized, feed-back loop (subhorizontal drill section as conventional diameter).

The delivery heads (B) or / and (C) can also have direct flow feedback as in 3B (A) have.

By the same method, there could also be quadruple or multiple cross-polarized feedback projects, with four or a multiple of 2 holes given.

Here are the different inflow components of ( 1 ) to ( 12 ) are numbered in the order of the inflow direction.

The functionality is the same as in 3A ,

The arrows show the direction of the water circulation.

The variant can be extended again to increase the thermal efficiency as in 3And ,

"The Reservioir model with triple cross-polarized feedback loop, with deflected slim-hole or CT holes.

3And
Here is the schematic example in vertical section of a Reservioir model with triple cross-polarized feedback loop with deflected slim-hole or CT holes.

Subhorizontal DW2 drill sections ( 2 ) 6 ) 10 ) are deflected slim-hole or CT holes.

Here are the various inflow components of ( 1 ) to ( 12 ) are numbered in the order of the inflow direction.

The conveying heads (B) or / and (C) can also be used in direct feedback circulation as in 3B be.

By the same method, there could also be quadruple or multiple cross-polarized feedback projects, with four or a multiple of 2 holes given.

This example in horizontal section of a reservoir model with triple cross-polarized feedback loop, as well as in 3H look even if the arrangement of the inflow is not the same as in 3And is.

In 3H The conveying heads (B) and / or (C) can also be used in direct feedback circulation as in 3B be.

To simplify the understanding of the project, shows 3E a schematic example in a 3D view of a reservoir model with triple cross-polarized feedback loop, as in 3D ,

Also in 3H are the different inflow components of ( 1 ) to ( 12 ) are numbered in the order of the inflow direction.

The project with (subhorizontal DW2 drill sections as deflected slim-hole or CT boreholes) can also be used in the simplest form of the double cross-polarized reservoir variant with deep circulation feedback as in 3A be. This variant is in 3F displayed.

Again, the various inflow components of ( 1 ) to ( 10 ) are numbered in the order of inflow direction.

These are also the sidetrack points ( 2 ) and ( 7 ). A delivery head (A) or (B) can also be used in direct feedback circulation as in 3B (A) be.

The corresponding horizontal section of the 3F is in 3G shown. Again, the various inflow components of ( 1 ) to ( 10 ) in the order of the inflow direction. These are also the "sidetrack points" ( 2 ) and ( 7 ). (A) and (B) are, as always, the heat exchangers.

3i
A variant of all these projects with solar collectors is in 3i shown. 3i shows a schematic example in vertical section of a variant of 3B Here, the Reinjektionspunkt can be coupled to the surface with solar panels. This is a good solution for regions in low latitude and depending on the flowing water temperature.

Solar collectors can be used in all points such as (A), (B) or (C) with direct flow feedback.

In a reservoir, several production wells and / or injectors can land 3D ,

3M is a variant of 3D with horizontal bores in conventional diameter

This is a schematic example in vertical section of a reservoir model with triple cross-polarized feedback loop, with main reservoir ( 1 ) and two sub-reservoirs (subhorizontal drill section as conventional diameter). The arrows show the direction of the water inflow.

The delivery heads (B) or / and (C) may also have direct flow feedback such as (B).

(A) and (C) are heat exchangers, (B) a flow-feed back.

The horizontal holes can be replaced by several Slim-Hole DP or CT holes as in 3And ,

By the same method, there could also be quadruple or multiple cross-polarized feedback projects, with four or a multiple of 2 holes given.

As a summary of the functionality of these project types is in 4 a three-dimensional model of the water supply shown.

This is a 3 dimensional scheme of a polarized reservoir project where the "sidetrack points" exit from a DW1 that is above the plane p.

PHASE 3. PREPARATION OF THE MEMORY FLOW VOLUME TO THE RESERVOIR

After the injector has been drilled and tubed, the reservoir must be prepared for infiltration with frac or stimulation techniques if there is not enough permeability.

Hydrochloric acid stimulation methods are usually used in carbonates. Fracverfahren in rocks that are not fractured or verkarstet and with less associated secondary porosity.

The innovation for the frac processes in these types of projects has already been presented above.

These new methods for frac operations are in 10 to 22 illustrated.

Medium Reservoir Model PROJECT PHASES AND PROJECT VARIANTS

Subsequently, solutions for the resource reservoir model innovation are described here.

5 is a schematic example in vertical section of a mid-reservoir project with distanced PSP and ISP.

An ideal reservoir is first searched for using geophysical methods. After the exploration phase, the planning phase and the drilling of the production well DW1 ( 2 ).

The bore of the deflected horizontal phase DW2 ( 5 ) to the reservoir ( 3 ) and testing the reservoir in the area ( 4 ) follows.

When the reservoir is successfully tested, the bore of the injection well DW1 ( 1 ) and the deflected injector DW2.

In horizontal section, the project can be better in 6 be seen where ( 1 ) the injection well is ( 3 ) and ( 4 ) are the deflected injectors DW2 that open as a "fan system" before they are new to the reservoir ( 5 ) converge. The water flow continues in a "fan system" consisting of DW2 production wells in the pilot hole or production well DW1 ( 2 ) where the water is pumped by underwater pumps up into the heat exchanger.

The inflow of water into the reservoir can take different variants. Through the bottom of the hole as in 6 or in parallel scheme as in 6A where the piping ( 2 ) 3 ) in ( 4 ) and serve as poles of Frac operations. The inflow of water will therefore be in the direction of the arrows.

Also for the middle reservoir model different variants are possible to increase the efficiency.

The central variant of the medium reservoir model with near PSP and ISP and several "slim-holes" or CT injectors DW2 and wells DW2 is in 6B illustrated.

The arrows show the direction of the water flow. From the sidetrack point of the DW1 injector drive the DW2 injectors ( 3 ) in a subhorizontal direction to the reservoir ( 5 ). The water flow continues through the production wells DW2 ( 4 ) enter the production well DW1 through the sidetrack points (D).

A variant of this model with higher hydraulic efficiency is in 6E shown. Here is the production hole DW1 ( 2 ) + DW2 ( 6 ) a conventional diameter production well DW1 + DW2.
Central / Subcentral variant.

Other variants with higher thermal efficiency are possible.

6C shows a schematic example in the vertical section of a central reservoir project with near PSP and ISP and multiple injectors DW2 ( 6 ) and production wells DW2 ( 5 ). This is the eccentric variant.

The arrows show the direction of the water flow. ( 1 ) is the injector DW1, ( 2 ) is the production well DW1, ( 3 ) and ( 4 ) are the sidetrack points, ( 7 ) is the reservoir.

This variant can be made simpler for the water flow but in this case the thermal efficiency will be lower.

One can understand the functionality of this project better if one uses the 6F and 6G DW2 places "slim-hole" or CT production wells in place of a single production well. One can then use a symmetrical or asymmetrical variant similar to 6F and 6G produce.

For a higher hydraulic efficiency, the variant used in 6D is shown. The production hole ( 2 ) ( 5 ) now consists of a conventional diameter production well DW1 ( 2 ) + DW2 ( 5 ).

This is a medium reservoir project with near PSP and ISP, with several injectors DW2 ( 4 ) and only one production well.

6F shows the symmetrical variant of 6D ,

This is a schematic example in the horizontal section of the Mittel Reservoir project with near PSP (B) and ISP (A), with several DW2 injectors ( 3 ) 4 ) and only one production well DW1 + DW2 ( 2 ). Eccentric variant. Symmetrical injectors DW2 ( 3 ) ( 4 ) Arrangement.

The arrows ( 7 ) show the direction of the water flow. The water in the reservoir ( 6 ) is pumped through the underwater pumps ( 5 ) pumped to the surface.

The same project can be realized in an asymmetric variant like 6G shows.

Here take the injectors ( 3 ) an asymmetric arrangement relative to the production well ( 2 ).

The arrows ( 7 ) show the direction of the water flow. The water in the reservoir ( 6 ) is pumped through the underwater pumps ( 5 ) pumped to the surface.

INNOVATIONS FOR HYDROTHERMAL GEOTHERMIA

Multilateral drilling and CT, "Slim Hole" DP Sidetrack drilling has never been used in geothermal energy.

The application of this technology can significantly increase the efficiency of a project.

In 7 is a schematic example in the vertical section of a DW2 ( 5 ) distracted from a DW1 (sidetracked) ( 1 ) and in the direction of a target ( 8th ) drilled.

This is a method of producing hot water or steam.

The innovation is the application of "multi-lateral wells" for hydrothermal or hydrogeothermal geothermal energy when hot water is present in the formation and only needs to be pumped to the surface. When creating multilateral holes ( 2 ) from a main bore ( 1 ) as in 8th you can simultaneously multiple targets / reservoirs ( 3 ) and the total flow rate / production can be increased.

Each lateral hole may contain its own underwater pump, or production may be done with an underwater pump in the main bore. The hydraulic efficiency must be calculated accurately and in this case, flow restrictors (Flow Restrictors) ( 9 ) at the head of each lateral bore serve to equalize the pressure in each lateral bore.

After flowing through the heat exchanger, the water must be pumped back into the deep formations. This can be done through a single hole.

However, the reinjected water has to land far away from the production wells.

FRAC OPERATIONS

The Fracverfahren in the polarized and middle-reservoir projects are similar, only the dipole orientation and geometry can vary.

23 is a schematic theoretical representation of the eigenvectors of a geodynamic stress field where normally sigma 1 is subvertical sigma 2 and sigma 3 are perpendicular to each other and to sigma 1.

The azimuth of Sigma 2 and Sigma 3 is dependent on tectonic stress.

The orientation of the dipoles (P1, P2) between two parallels DW2 as in 18 should be planned precisely as a function of the geodynamic stress field to produce the optimal flow line (directivity) into the reservoir.

An optimal situation arises when the perforations lie on the level Sigma 2 sigma 1.

In such an optimal situation, the gap (fracture) in a "stress-confinement" layer ( 1 ), from two poles ( 2 ) at the level of vertical vectors as in 19 propagate.

10 and 11 are two examples of frac mechanisms for a polarized reservoir project.

The 10 is a schematic example in the horizontal section of a time-synchronized bipolar frac method between ( 1 ) 2 ) 3 ) DW2 Injector Ends and the Production Drill ( 8th ) (longer arrows) and between sub-parallel DW2 injectors (shorter arrows).

The arrows show the direction of the perforations and the initial spread of the frac pressure. Theoretically, the initial pressure field equipotential should have an emispheric shape.

At the bottom of the production well ( 10 ), the formation can be fractured with high-density mud. (intensive LOT / FIT) ( 7 ).

Between the casings, however, the frac is carried out in the bipolar mechanism using a conventional frac method. The arrows ( 6 ) show the initial pressure direction of the water from the perforation ( 4 ) exit.

Each pair of opposing arrows is a dipole.

The poles of dipole D2 are P1 and P2.

When multiple dipoles are activated we have a multipolar frac mechanism.

When the frac operation at the bottom of the production well is done by conventional frac methods, the fractures initiated are focused in the direction of the perforations.

That's the case in 11 where is a schematic example in the horizontal section of time-synchronized bipolar frac method between ( 1 ) 2 ) 3 ) DW2 Injector Ends and Production Bore ( 8th ) is schematized.

The Frac methods between subparallel DW2 injectors are also shown.

Between the piping, the frac can be done in the multipolar mechanism by conventional frac method to increase the storage volume.

At the end of the DW2 ( 1 ) and ( 2 ) two or more dipoles are active, just like at the end of ( 2 ) and ( 3 ).

20 and 21 show the timing and synchronization of the frac process as shown in the pressure-time diagram. This time course should be the same in all active poles.

For eccentric central reservoir with many injector and DW2 producer. applies 12 , There is a schematic example in horizontal or vertical section of time-synchronized bipolar frac method between "slim-hole" or CT injection and production DW2 (FIG. 2 ) into the storage and inflow volume ( 1 ).

Each dipole consists of a pair of opposing arrows ( 3 ).

If only one dipole is used, we are in the domain of the bipolar frac process. If several dipoles are active here, then we are in the domain of the multipolar frac process

The case of an eccentric center reservoir project with many DW2 injectors and a DW2 production well with different frac geometries will be in 13 . 16 . 17 Illustrated.

In 13 is the pressure spread of 3 injector poles ( 3 ) of a single propagation of a higher pressure pole ( 4 ) of the producer.

In 16 a mixed geometry is shown with one pole from the coupling of the poles ( 3 ) and ( 4 ) consists.

In 17 the poles of the DW2 injector are produced on the injector sole ( 5 ). At the Producer, the poles of the lateral perforations ( 6 ) correspond. As shown, a dipole consists of opposing pressure vectors, for example ( 3 ) and ( 4 ).

In central central reservoir with many injector and DW2 producer as in 14 , the frac operations in a bottoming configuration can be like 14 or DW2 parallels configuration like 6A be performed.

In 14 is a schematic example in the horizontal or vertical section of time-synchronized bipolar or multipolar Fracverfahren between "slim-hole"
or CT injectors ( 2 ) and production DW2 ( 4 ) into the storage and inflow volume ( 1 ), represented by the DW2 outsole. (Central central reservoir with many injector and production wells DW2). The poles are represented by the vectors ( 3 ) and ( 4 ).

The case of central central reservoir with many injectors and a DW2 production well will be in 15 shown.

This is a schematic example in horizontal or vertical section of time-synchronized bipolar or multipolar frac methods between "slim-hole" or CT injectors ( 5 ) and a conventional diameter production DW2 ( 5 ) into the storage and inflow volume ( 1 ) through the DW2 drill sole. The poles with higher pressure ( 4 ) are 3 poles with lower pressure ( 3 ) across from.

Claims (11)

Process for the exploration, development and production of geothermal energy by inflow of water through deep geological formations (DDS: Deep Directivity Systems, Polarized Reservoir Method) comprising the following steps: - Searching for and exploring an ideal reservoir ( 2 . 2A . 2 B . 2C ) with high formation temperature - drilling a subvertical or deflected production well into the reservoir as in 2 . 2A . 2 B and 2C Specified - Log measurements in the well and reservoir formation and testing for porosity, permeability and geomechanical parameters - Possible test to prepare the Frac or other stimulation methods for generating a storage inflow volume (collector) if sufficient permeability is not available , as in 2 . 2A . 2 B . 2C . 3X . 3X . 10 . 11 . 18 . 19 . 20 . 21 and 22 Specified - Drilling of Subvertical Major Injection Hole (DW1) with ISP (Starting Point of Injection Hole) far from PSP (Start of Production Hole), either to Sidetrack or to Reservoir Vertical Dust ( 3X . 3Z ) - Log Measurements and Hole Testing - Hole Drilling - Sidetracking and Drilling of One or More DP or CT DW2 Low Injection Wells from Injector DW1 in Subhorizontal Drilling Direction to the Reservoir Producer Collector ( 1 . 2A . 2 B . 2C . 3X . 3Y . 3And . 3F . 3G . 3H ), where landing point and inflow geometry depend on the structural and petrophysical properties of the reservoir - injection well DW2 - performing frac or other stimulation procedures if there is insufficient permeability, as in 10 . 11 . 16 . 19 . 20 . 21 and 22 Specified - Testing and commissioning of the geothermal project with feedback loop (feedback loop) on the surface ( 3Z ) Method according to claim 1 for expanding the drilling operation and preparing a single injection bore of conventional diameter ( 3Z ( 1 ) 2 )) instead of the injector system DW1 + DW2 with Slim-Hole DP or CT DW2 A method of exploration, development and production of geothermal energy by water inflow over cased wells in deep geological formations [double cross-polarized feedback-loop reservoir model (Feed-Back Loop)] according to claim 1, comprising the steps of: - planning a double cross-polarized reservoir Model with feedback loop (feed-back loop) as in 3F specified - search and exploration of two ideal, widely separated reservoirs (( 3F ( 4 ) 9 )), 2 . 2A . 2 B . 2C ) with high formation temperature - drilling of two sub-vertical or deflected production wells (( 3F ( 10 ) 5 ), (A), (B)) with PSP in (A) and (B) in both reservoirs as in 2 . 2A . 2 B . 2C and 3F ( 10 ) 5 ) - Log measurements in both wells and reservoir formations and testing for porosity, permeability, and geomechanical parameters - Drilling of wells - Possible test to prepare Frac or other stimulation techniques for creating a storage inflow volume (collector) into the well both reservoirs ( 2 . 2A . 2 B . 2C . 3X . 3Y . 10 . 11 . 18 . 19 . 20 . 21 . 22 ) if sufficient permeability is not available - drilling a subvertical main injection well (DW1) ( 3F ( 1 ), (A)) with ISP in (A), either to the sidetrack or to the reservoir vertical ( 3X . 3Z ) - log measurements and hole testing - tubing - sidetracking and drilling of one or more DP or CT injection wells DW2 of small diameter (slim-hole) ( 3F ( 3 )) from DW1 in a subhorizontal drilling direction to the reservoir production collector (( 3F ( 4 )), 1 . 2A . 2 B . 2C . 3X . 3Y . 3And . 3F . 3G . 3H ), where the target and inflow geometry depend on the structural and petrophysical properties of the reservoir - injection well or injection wells DW2 - performing frac or other stimulation procedures when there is insufficient permeability, as in 10 . 11 . 16 . 19 . 20 . 21 . 22 Specified - Circulation System Testing - Drilling of Subvertical Main Injection Well (DW1) ( 3F ( 6 ), (B)) with ISP in (B) to the sidetrack or reservoir vertical vale ( 3X . 3Z ) - Log measurements and testing of the bore - Casing of the bore - Sidetrack and drilling of one or more DP or CT injection wells DW2 with low Diameter ( 3F ( 8th )) from DW1 in a subhorizontal drilling direction to the reservoir producer collector ((FIG. 3F ( 9 )), 1 . 2A . 2 B . 2C . 3X . 3Y . 3And . 3F . 3G . 3H ), where landing point and inflow geometry depend on the structural and petrophysical properties of the reservoir - injection well or injection wells DW2 - performing frac or other stimulation procedures when there is insufficient permeability, as in 10 . 11 . 16 . 19 . 20 . 21 and 22 specified - testing and commissioning of the geothermal project Method according to claim 3 for expanding the drilling process and preparing two injection bores of conventional diameter (( 3A ( 2 ), ( 4 ) 8th ) 5 )), 3B . 3C ) instead of injection wells DW1 + DW2 with Slim-hole DP or CT DW2 Methodology for exploration, development and production of geothermal energy through water inflow over cased wells in deep geological formations (triple or multiple cross-polarized reservoir model with feedback loop); 3And . 3H ) according to claim 1 and 3, comprising the following steps: - planning of a triple or multiple cross-polarized reservoir model with feedback loop ( 3And ) - Search and Exploration of 3 or more Reservoirs - Drilling a DW1 Production Well in Each Reservoir - Log Measurements and Testing of All Three Production Holes and Reservoirs - Production Wells Drilling - Drilling a DW1 Injection Hole Near Each Production Well DW1 - Piping the Three Injection Wells DW1 Sidetrack from the injection wells DW1, one or more injection wells DW2 (FIG. 3And ( 2 ) 6 ) 10 )) and bore to the target in the next reservoir ( 3And ( 3 ) 7 ) 11 )) - Piping of injection wells DW2 - Test and commissioning Method according to claim 1, 2, 3, 4 and 5 for the realization of one, two or more surface feedback systems (flow-feed-back loop systems) as a replacement for the heat exchangers ( 3B , (A)) Method according to claim 1, 2, 3, 4, 5 and 6 with regard to the drilling of several production or injection wells into the same reservoir ( 3M ) for the realization of a triple or multiple cross-polarized reservoir model with feedback loop (feed-back loop), main reservoir and secondary reservoir, with one or more injector DW2 Method for artificial fracturing of rock formations (frac method) by time-synchronized bipolar or multipolar frac methods with different geometric arrangement and orientation of the poles (perforations) ( 6A . 10 . 11 . 12 . 13 . 14 . 15 . 16 . 17 . 18 . 19 . 20 . 21 . 22 ) Application of multilateral well system technology and slim-hole DP and / or CT sidetrack drilling in geothermal projects Application of flow restrictors for pressure and inflow equalization in various drilling areas in multilateral wells or in sidetracked wells The method of claim 1, 2, 3, 4 and 5 for installing one, two or more solar collectors in the surface feedback loop (flow feedback loop) as a replacement for the heat exchangers ( 3i )

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