Abstract: A method and apparatus for desalinating water combined with power generation, wherein a desalination system is used for desalinating coastal seawater and is operationally related to a power generation system, wherein such dual purpose co-generation facility captures the heat vapor exhausted or a steam turbine generator's condenser is replaced by the desalination plant's heat exchanger enabling such captured heat energy to reduce the energy requirements of the desalination plant, and wherein brine solution being utilized by the desalination plant is circulated from and to the substrata sea water table via supply and return wells.

Abstract: Methods and apparatus for facilitating optical communications and sensing, with downhole optical or other sensors, in high temperature oilfield applications. The apparatus can include a downhole telemetry cartridge for downhole use at temperatures in excess of about 115 degrees Celsius. The apparatus can also include a downhole light source optically connected to the telemetry cartridge. The light source may include at least one remotely pumped laser optically connected to a surface pump laser via optical fiber(s). The remotely pumped laser may drive the downhole optical or other sensors for their operations.

Abstract: Structures can be formed downhole by accumulating already existing materials and/or materials introduced into a well to perform a specified function. The formed structures may be used to obstruct fluid flow of production or injection fluids, carry mechanical loads, control electrical or magnetic properties of components, mechanically actuate a component, as well as others. The materials may be induced to form the specified structure, such as by application of a potential downhole. For example, electrical, magnetic, sonic, biological potentials, or a combination thereof may be established downhole to form specified structures in specified locations to perform specified functions.

Abstract: A method, system, and method for developing the system, for producing hydrocarbons from a plurality of hydrocarbon containing reservoirs is described. The system includes at least one conventional hydrocarbon reservoir and at least one natural gas hydrate reservoir. The system also includes a production facility, including water separation apparatus, which is in fluid communication with the at least one hydrocarbon reservoir and the at least one natural gas hydrate reservoir. The production facility can separate hydrocarbons and water concurrently received from the first conventional hydrocarbon and the second natural gas hydrate reservoirs. The at least one hydrocarbon reservoir and the at least one hydrate reservoir can be concurrently developed. Or else, the at least one hydrate reservoir can be developed later in time and then fluidly connected to the production facility.

Abstract: A well servicing fluid is disclosed. The well servicing fluid is formulated with components comprising: an organic salt, the organic salt being the product of an organic acid and an organic amine base; and an aqueous based solvent. A method of servicing a well is also disclosed.

Abstract: A hanger system is provided for supporting a cable-supported dewatering pump in a gas well. A dewatering pump is supported in a downhole location by a cable. A cable hanger bears the weight of the cable and the weight of the dewatering pump. A pulling tool is configured to detachably connect to the cable hanger and to support the weight of the cable hanger, cable and gas well dewatering system as it is pulled out of a seated position in the well.

Abstract: The current application discloses methods and systems for conducting operations to subterranean formations. The system comprises a platform, a grillage mounted on the platform, at least one module for treating the subterranean formation, and a plurality of locks that mechanically engage the grillage with the module. Each lock comprises a first plate, a second plate and a connector that connects the first plate and the second plate. The first plate is configured to mechanically engage the grillage, the second plate is configured to mechanically engage the module for treating the subterranean formation.

Abstract: The subject matter of the invention is a separating device for removing sand and rock particles which is suitable as an integral component part of extraction equipment for the extraction of liquids or gases from deep wells, the separating device comprising at least one ceramic filter module (1), the filter module (1) comprising a) an annular stack (6) of brittle-hard annular discs (7), the upper side (16) of which has at least three elevations (8) uniformly distributed over the circular circumference of the discs, the discs (7) being stacked and braced in such a way that a separating gap (9) for the removal of sand and rock particles is present in each case between the individual discs (7), b) a coupling-on element (10) at the upper end and a coupling-on element (11) at the lower end of the annular stack (6), c) a clamping device (14, 15) for the axial bracing of the annular stack (6), d) an outer cage (5) for the mechanical protection of the filter module (1), e) a coupling element (12) at the upper end a

Abstract: The method begins drilling a borehole from the surface to an underground shale matrix. A pipe is inserted into the borehole. Openings are created in the pipe in fluid communication with fractures in the shale matrix. The interior surface of at least one section of pipe is coated with a contaminant-capturing substance. Fracturing fluid including water, proppants and various chemicals is pumped through the pipe and into the fractures in the shale matrix. The fluid re-enters the pipe from the shale matrix and moves toward the surface through the coated pipe section where contaminants are sequestered by the coating. Natural gas or oil from the fractured shale then enters the pipe and moves to the surface to be collected. The coated pipe section remains in the ground permanently such that the necessity of disposing of the captured contaminants is eliminated. Alternatively, the contaminant-capturing substance can be coated onto the proppants which remain lodged in the fractures in the shale matrix.

Abstract: An oilfield apparatus includes an oilfield element made of a composite that includes a matrix material; and a plurality of functionalized graphene sheets dispersed in the matrix material. A method of oilfield operation includes selecting an oilfield apparatus having an oilfield element, wherein at least a portion of the oilfield element is made of a composite comprising a plurality of functionalized graphene sheets dispersed in a matrix material; and using the oilfield apparatus in an oilfield operation, thereby exposing the oilfield element to an oilfield environment. A method for modifying a functionalized graphene sheet includes obtaining the functionalized graphene sheet; and subjecting the functionalized graphene sheet to atom transfer radical polymerization to attach polymers on surfaces of the functionalized graphene sheet. The polymers attached to the surfaces of the functional graphene sheet may comprise co-polymers or magnetic particles.

Abstract: A method of actuating a well tool utilizing first and second pressure sources includes the steps of: placing an actuator chamber in communication with the first pressure source, thereby displacing a piston from a first position to a second position; and then placing another chamber in communication with the second pressure source, thereby displacing the piston to a third position. A multi-position actuator includes an operating member which displaces to operate a well tool, a first position of the operating member corresponding to a pressure source being in communication with a chamber and another pressure source being in communication with another chamber, a second position of the operating member corresponding to the same pressure source being in communication with both of the chambers, and a third position of the operating member corresponding to the pressure sources being connected to the chambers oppositely to that of the first position.

Abstract: The technical challenges for a smooth transition between using both a thermodynamic hydrate inhibitor (THI) and a kinetic hydrate inhibitor (KHI) to simply using only the KHI in multiple tie-in gas natural gas production systems is solved by adding more THI in a first pipeline leg of the production system while ceasing adding THI in a second pipeline leg of the system. Further, more KHI is added into the second leg of the system, and subsequently THI is gradually and/or slowly reduced in the remaining legs of the system until only KHI is being injected, after which the KHI amount in all legs may be reduced to the equilibrium or steady-state levels.

Abstract: Fluids and associated methods useful in subterranean applications are provided. Compositions are provided that may be useful in subterranean applications for addressing, among other things, drill string sticking problems. More particularly, spotting fluid compositions are provided having a water insoluble external phase fluid; a water soluble internal phase fluid; and an ether carboxylic acid emulsifying agent. Additional optional components may be used, such as viscosifiers, weighting agents, and wetting agents.

Abstract: Fluids and associated methods useful in subterranean applications are provided. More particularly, methods of reducing drill string sticking are provided, which include: providing a spotting fluid composition comprising a water insoluble external phase fluid, a water soluble internal phase fluid, and an ether carboxylic acid emulsifying agent; introducing the spotting fluid to the vicinity of a desired portion of a drill string; and allowing the spotting fluid to interact with a portion of material surrounding the desired portion of the drill string spotting fluid. Compositions are provided that may be useful in subterranean applications for addressing, among other things, drill string sticking problems. Additional optional components may be used, such as viscosifiers, weighting agents, and wetting agents.

Abstract: A method of treating liquid, particularly an oil/water mixture, in an oil well pipe, wherein a radio frequency propagating electrical field is established in the liquid in the pipe cause the formation of seed crystals or scale-forming material in the liquid, on which seed crystals asphaltenes and/or paraffin waxes in the liquid are deposited so that they are carried through the pipe with the liquid in preference to being deposited on the pipe wall.

Abstract: A system transmits a wireless power transmission from a bottom hole assembly of a drill string. The system has a downhole component having a wireless power transmitter adapted to wirelessly transmit at least one wireless power transmission and a wireless power receiver adapted to receive the at least one wireless power transmission.

Abstract: Provided are coated oil and gas well production devices and methods of making and using such coated devices. In one form, the coated device includes one or more cylindrical bodies, hardbanding on at least a portion of the exposed outer surface, exposed inner surface, or a combination of both exposed outer or inner surface of the one or more cylindrical bodies, and a coating on at least a portion of the inner surface, the outer surface, or a combination thereof of the one or more cylindrical bodies. The coating includes one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating. The coated oil and gas well production devices may provide for reduced friction, wear, erosion, corrosion, and deposits for well construction, completion and production of oil and gas.

Abstract: In one embodiment, a method for drilling a wellbore includes injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate. The tubular string includes: a drill bit disposed on a bottom thereof, tubular joints connected together, a longitudinal bore therethrough, and a port through a wall thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The cuttings and drilling fluid (returns) flow to the surface via an annulus defined between the tubular string and the wellbore. The method further includes rotating the drill bit while injecting the drilling fluid; remotely removing a plug from the port, thereby opening the port; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint or stand of joints to the tubular string. The injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the joint or stand to the drill string.

Abstract: Provided are coated sleeved oil and gas well production devices and methods of making and using such coated sleeved devices. In one form, the coated sleeved oil and gas well production device includes one or more cylindrical bodies, one or more sleeves proximal to the outer diameter or inner diameter of the one or more cylindrical bodies, hardbanding on at least a portion of the exposed outer surface, exposed inner surface, or a combination of both exposed outer or inner surface of the one or more sleeves, and a coating on at least a portion of the inner sleeve surface, the outer sleeve surface, or a combination thereof of the one or more sleeves. The coating includes one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating. The coated sleeved oil and gas well production devices may provide for reduced friction, wear, erosion, corrosion, and deposits for well construction, completion and production of oil and gas.

Abstract: Oil shale and/or oil sands are utilized to generate electricity and/or steam at the site of the oil shale/sands deposit in an in situ process for recovering oil from the deposit. Bulk shale/sands material is removed from the deposit and combusted to generate thermal energy. The thermal energy is utilized to heat water to generate steam. The steam can be used directly in the in situ process or utilized to drive a steam turbine power generator located in close proximity to the deposit to generate electricity. The electricity generated on-site may be utilized to drive an in situ conversion process that recovers oil from the oil shale/sands deposit. Also, the exit steam generated by the on-site turbine generator can be used on-site to drive the in-situ conversion process.

Abstract: A hydrostatic set module configured with a wireless trigger mechanism to allow wireless activation thereof from an oilfield surface. The trigger mechanism includes a charge for exposing the module to wellbore pressures and allowing it to behave as an intensifier for actuation of a downhole device such as a production packer. The mechanism also includes a sensor for detection of the wireless communications along with a processor for analysis thereof and to direct spending of the charge. Pressure pulse or other wireless communication forms that are suitable for the downhole environment may be transmitted from surface in a variety of different signature patterns for responsive analysis by the trigger mechanism.

Abstract: An above-motor mixed flow booster pump combined with a fluid crossover that directs up into the inside of an inverted shroud to allow enhanced gas separation. A gas and liquid separator is used to enhance separation. The system is simple and provides increased gas handling capability for high flow or low flow gas well dewatering applications, including vertical wells, horizontal wells, slant wells. The boost pump allows the moving of a mixed flow upwards to the top of an inverted shroud in wells lacking the required pressure.

Abstract: Embodiments of the invention relate to a process for providing a pumpable hydrate slurry in a hydrocarbon pipeline fluid mixture having a water-cut greater than about 50 volume percent. In one or more embodiments the process comprises treating the fluid mixture with an anti-agglomerant and adding water to the fluid mixture in an amount sufficient to lower the gas-water ratio sufficiently to achieve a pumpable hydrate slurry. Also disclosed are methods for producing hydrocarbons utilizing a process for providing a pumpable hydrate slurry in a hydrocarbon pipeline fluid mixture having a water -cut greater than about 50 volume percent.

Abstract: A top drive system for wellbore operations and method for facilitating rotation thereof. The system includes a main body and a motor, preferably a salient pole motor. A motor shaft extends from the motor and a gear system is driven by the shaft and interconnected with a drive shaft. The gear system has a housing and a bearing retainer integral with the housing and is driven by the motor apparatus so that driving the gear system drives the drive shaft.

Abstract: This invention is a solvent based gravity drainage process whereby the vertical growth rate of the chamber is restricted by placing, monitoring and managing a buoyant gas blanket at the top of the vapour chamber. This invention reduces the heat loss to the overburden as well as providing a means to preserve a barrier layer of bitumen saturated reservoir sand at the top of the pay zone in reservoirs where there is limited or no confining layer present.

Abstract: The present disclosure is directed to a system and method of sustainable economic development, such as development through an integrated production of renewable energy, material resources, and nutrient regimes. In some embodiments, the system utilizes resources extracted from renewable energy sources to assist in the capture of energy from other renewable energy sources. In some embodiments, the system utilizes energy from renewable energy sources to extract resources from other renewable energy sources.

Abstract: Provided are coated sleeved oil and gas well production devices and methods of making and using such coated sleeved devices. In one form, the coated sleeved oil and gas well production device includes an oil and gas well production device including one or more bodies and one or more sleeves proximal to the outer or inner surface of the one or more bodies, and a coating on at least a portion of the inner sleeve surface, outer sleeve surface, or a combination thereof, wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated based nickel-phosphorous composite with a phosphorous content greater than 12 wt %, graphite, MoS2, WS2, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof.

Abstract: A technique enables wireless communication of signals in a well. The technique is employed for communication of power signals and/or data signals between a mother wellbore and at least one lateral wellbore. A first wireless device is positioned in a mother wellbore proximate a lateral wellbore, and a second wireless device is positioned in the lateral wellbore. The power and/or data signal is transferred wirelessly between the first and second wireless devices via magnetic fields. A plurality of the first and second wireless devices may be employed in cooperating pairs to enable communication between the mother wellbore and a plurality of lateral wellbores.

Abstract: The present disclosure relates to a pump mechanism driven by differential pressure conditions and method for delivery of materials. In one embodiment, the pump mechanism may be used to deliver treatment chemical to a plunger apparatus or directly to a wellbore by exploiting pressure conditions found at a well. In certain embodiments, the pump mechanism is able to balance high pressure conditions available within a petroleum formation against low pressure conditions present in a common flow line serving the well. In so balancing these pressures, the pump mechanism is able to automatically tune itself to the needs of the well, ensuring continued operation over a wider range of operating conditions. The pump mechanism has the further advantages of lower operation costs and less environmental impact as compared with existing pumps.

Abstract: A technique enables improved efficiency with respect to various coiled tubing and well servicing operations. The technique utilizes a combined mobile unit having several types of equipment combined into at least one transportable unit. The combined mobile unit may comprise a coiled tubing reel having coiled tubing, a well servicing system mounted to deliver material through the coiled tubing, and/or other well servicing components with the gas delivery system. The gas delivery system has a pressurized liquid gas vessel to deliver gas that can be used for well servicing operations, including purging material from coiled tubing.

Abstract: A well screen assembly has an elongate base pipe having apertures therein. A filtration layer resides around the base pipe. A drainage assembly resides between the base pipe and the filtration layer. The drainage assembly includes a plurality of elongate risers carried on a mesh. The drainage layer supports the filtration layer apart from the elongate base pipe and defines an elongate passage between the base pipe and the filtration layer that communicates fluid laterally through the drainage assembly.

Abstract: Methods and apparatus are described that combine a measurement of the physical velocity of material within the annulus of a well between the drill pipe and the wall of the well with a measurement of the area of the flow as determined from a measurement of distance between the drill pipe and the wall of the hole to determine the actual material volumetric flow rate. Changes in volumetric flow rate at one or more points along the well can be used to determine the occurrence and location of well dysfunctions. This knowledge can then be used to make decisions about treating well dysfunctions which will lead to more efficient use of drilling rig time.

Abstract: The present invention provides a formulation for use in the treatment of corrosion and metal sulphide scale deposits in aqueous systems, said formulation comprising a tetrakis (hydroxyorgano) phosphonium salt (THP+ salt) and a primary, secondary or tertiary alcohol having an acetylenic bond in the carbon backbone. The invention also provides the use of such a formulation for treating corrosion of mild steel, copper or aluminium, and a method for treatment of an aqueous system containing or in contact with a metal sulphide scale while concomitantly inhibiting the corrosion of surfaces in contact with said aqueous system, which method comprises the addition to said aqueous system of a scale and corrosion inhibiting amount of such a formulation.

Abstract: The present invention relates to an apparatus and method for providing hydraulic load compensated time delay in downhole well operations. The apparatus includes a piston stem enclosed by a piston housing. An axial force, acting either in the direction of stretch or in the direction of compression, causes a pressure buildup in one of two hydraulic chambers which are each filled with an incompressible liquid and which are mutually connected through one or more throttle orifices. A sideways floating, supported piston sleeve is arranged between the piston stem and the piston housing.

Abstract: A power transmission system for use with downhole equipment in a borehole includes a power source that is positioned at the surface providing a DC power supply, a downhole DC/DC converter and a two-conductor cable connecting the power source and the downhole DC/DC converter. The power transmission system receives the DC voltage supply as an input and provides an output DC supply at a different voltage to the DC power supply for provision to the downhole equipment.

Abstract: Provided are coated oil and gas well production devices and methods of making and using such coated devices. In one form, the coated oil and gas well production device includes an oil and gas well production device including one or more bodies, and a coating on at least a portion of the one or more bodies, wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated based nickel-phosphorous composite with a phosphorous content greater than 12 wt %, graphite, MoS2, WS2, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof. The coated oil and gas well production devices may provide for reduced friction, wear, corrosion, erosion, and deposits for well construction, completion and production of oil and gas.

Abstract: An assembly for delivery of treatment fluid at a target location downhole. The assembly is configured to avoid any substantial loss of treatment fluid in advance of reaching the target location in spite of low well pressure or a potentially excessive depth of the location. The assembly also allows for loading with treatment fluid from a downhole end thereof so as to avoid driving treatment fluid through the entirety of a tubular accommodating the assembly. The assembly may employ a spot valve to enhance filling with treatment fluid along with a backpressure valve coupled to the spot valve on-site so as to avoid premature loss of treatment fluid during a delivery application.

Abstract: A method of actuating a well tool utilizing first and second pressure sources includes the steps of: placing an source, thereby displacing a piston from a first position to a second position; and then placing another chamber in communication with the second pressure source, thereby displacing the piston to a third position. A multi-position actuator includes an operating member which displaces to operate a well tool, a first position of the operating member corresponding to a pressure source being in communication with a chamber and another pressure source being in communication with another chamber, a second position of the operating member corresponding to the same pressure source being in communication with both of the chambers, and a third position of the operating member corresponding to the pressure sources being connected to the chambers oppositely to that of the first position.

Abstract: Embodiments of the present invention generally relate to methods and apparatuses for gripping and shearing a downhole cable. In one embodiment, a line cutter mandrel includes: a tubular mandrel; a pocket disposed along an outer surface of the mandrel and longitudinally coupled to the mandrel; a channel disposed through the pocket for receiving a cable; and a line cutter. The line cutter includes a blade, is operable to engage an outer surface of the cable in a gripping position, is operable to at least substantially sever the cable with the blade in a cutting position, and is operable from the gripping position to the cutting position by relative longitudinal movement between the cable and the pocket.

Abstract: A system and a method are disclosed for providing a downhole mechanical energy absorber that protects downhole tools from impact loads and shock loads that occur during run-in contacts, tool drops, perforating blasts, and other impact events. A continuous localized inelastic deformation of a tube is a primary energy absorber in a load limiting design of the downhole mechanical energy absorber.

Abstract: An apparatus, method, and system for actuating a wellbore tool includes a body having a chamber in which a movable member is disposed. The movable member may connect to a selected wellbore tool. Within the chamber is a controllable fluid that substantially prevents relative movement between the body and the movable member when exposed to an applied magnetic field. A generator applies the magnetic field to the fluid and may change the applied magnetic field in response to a first control signal to release the movable member from the body. A driver displaces the movable member relative to the body once the movable member is released from the body.

Abstract: A device and method for the reduction of vortex-induced vibration of a deepwater riser. A device for attachment to a structure, which is subject to movement relative to a fluid surrounding the structure, for reducing vortex-induced vibration effects on the structure, the device comprising: a flexible netting (4) interconnecting a plurality of relatively inflexible members comprising a plurality of elongate members (3) and a plurality of spacer members (6), wherein each elongate member has a first cuter boundary and each spacer member has a second outer boundary wherein the second boundary extends radially outward of the first outer boundary relative to the netting, over at least: a substantial portion of the boundary.

Abstract: The present invention is generally directed to systems and methods for mitigating temperature-related pressure buildup in the trapped annulus of an oil or gas well, wherein such systems and methods employ production and/or tieback casing having one or more pressure mitigating chambers., and wherein such chambers make use of pistons, valves, and burst disks to mitigate pressure increases within the annulus. Such systems and methods can provide advantages over the prior art, particularly with respect to offshore wells.

Abstract: Subterranean oilfield high-temperature devices configured or designed to facilitate downhole monitoring and high data transmission rates with laser diodes that are configured for operation downhole, within a borehole, at temperatures in excess of 115 degrees centigrade without active cooling.

Abstract: Transferring rotary power between a first rotating member and a second rotating member may performed by using a first element associated with the first rotating member; and a second element associated with the second rotating member. The first element and the second element may be configured to rotate the first rotating member either substantially synchronously or non-synchronously with the second rotating member. A hysteresis material may be utilized in either or both of the first element and the second element. A modulator may be used to control a speed of the first element or the second element.

Abstract: In some embodiments, an apparatus includes a tool for a downhole operation. The tool includes an electrical component. The tool includes a rechargeable energy storage device to supply power to the electrical component. The tool also includes a generator to supply power to the electrical component.

Abstract: The present invention generally relates to an expandable liner hanger capable of being expanded into a surrounding casing. In one aspect, an expandable tubular system is provided. The system includes an expandable tubular. The system further includes an expansion swage for expanding the expandable tubular, wherein the expansion swage is deformable from a compliant configuration to a smaller substantially non-compliant configuration. Additionally, the system includes a restriction member disposed on an exterior surface of the expandable tubular, wherein expansion of the expandable tubular in the location of the restriction member deforms the expansion swage from the compliant configuration to the smaller substantially non-compliant configuration. In another aspect, a method of expanding a liner hanger using a cone is provided.

Abstract: A centralizer having a body with an inner surface provided with a friction-reducing slider, typically located in an annular recess on the inner surface of the body of the slider, spaced from the ends of the body. The slider can be formed separately from a body of the centralizer and subsequently attached thereto on the inner surface so that it is adapted to bear between the outer surface of the tubing to be centralized and the inner surface of the centralizer. This reduces rotational torque transmitted between the centralizer and the tubing, and assists in maneuvering of the tubular string into the desired position in the well.

Abstract: A method of reclaiming a well completion brine solution containing metal impurities by introducing to the brine solution an organic chelant of the formula: and may be either a neutral compound, a corresponding salt, or a corresponding quaternary salt, wherein: D is F-A (Y3)u(Y4)v; R is independently selected from Cp or CpC(O); Cp is a C1-C36, preferably a C8-C36, hydrocarbyl group, optionally substituted with one or more substituents selected the group consisting of halogen, hydroxyl, sulfate, CH2CO2Z or —(CH2)nPO(OZ)2 groups; each A is independently selected from —N and —P; Y1 is independently selected from J, —[(F)-A(J)]w Y6 and R; J, R1, Y2, Y3, Y4, Y5 and Y6 are independently selected from the group consisting of —H, R, —(F)nCO2Z and —(CH2)nPO(OZ)2; each F is independently selected from a C1-C12 hydrocarbyl group, optionally substituted with one or more substituents selected from the group consisting of halogen, hydroxyl, sulfate, CH2CO2Z or —(CH2)nPO(OZ)2 groups; Z is —H, a balanced organic counte

Abstract: A method and system of detecting and mapping a subsurface hydrocarbon reservoir includes determining ratio data for a plurality of orthogonal spectral components of naturally occurring low frequency background seismic data. The ratio data may be compared, plotted, contoured and displayed as a subsurface hydrocarbon reservoir map or a hydrocarbon potential map. The ratio data may represent a vertical spectral component of the seismic data over a horizontal spectral component of the seismic data. The subsurface hydrocarbon reservoir map may include contouring the ratio data over a geographical area associated with the seismic data.