An in situ process for treating an oil containing formation is provided. The process may include providing heat from one or more heaters to at least a portion of the formation. The heat may be allowed to transfer from the one or more heaters to a part of the formation such that heat from the one or more heat sources pyrolyzes at least some hydrocarbons within the part. Hydrocarbons may be produced from the formation.

In situ thermal processing of an oil reservoir formation

In an embodiment, a method of treating a kerogen and liquid hydrocarbon containing formation in situ may include providing heat from one or more heat sources to at least a portion of the formation. Heat may be allowed to transfer from the one or more heat sources to a part of the formation. In some embodiments, at least a portion of liquid hydrocarbons in the part may be mobilized. At least a portion of kerogen in the part may be pyrolyzed. In certain embodiments, a pressure within at least a part of the formation may be controlled. The pressure may be controlled to be at least about 2.0 bars absolute. A mixture may be produced from the formation.

In situ recovery from a kerogen and liquid hydrocarbon containing formation

A process may include providing heat from one or more heaters to at least a portion of a subsurface formation. Heat may transfer from one or more heaters to a part of a formation. In some embodiments, heat from the one or more heat sources may pyrolyze at least some hydrocarbons in a part of a subsurface formation. Hydrocarbons and/or other products may be produced from a subsurface formation. Certain embodiments describe apparatus, methods, and/or processes used in treating a subsurface or hydrocarbon containing formation.

Thermal processes for subsurface formations

A oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H 2 , and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat sources may be used to heat the formation. The heat sources may be positioned within the formation in a selected pattern.

In situ thermal processing of an oil shale formation using a pattern of heat sources

An in situ process for treating a tar sands formation is provided. The process may include providing heat from one or more heaters to at least a portion of the formation. The heat may be allowed to transfer from the one or more heaters to a part of the formation such that heat from the one or more heat sources pyrolyzes at least some hydrocarbons within the part. Hydrocarbons may be produced from the formation.

In situ thermal processing of a tar sands formation

The transit time of acoustic waves between a generator and a receiver positioned across a fluid chamber is determined by generating acoustic waves using a self-purging pneumatic sound generator, a transducer adjacent the outlet of the sound generator, and a receiving transducer positioned away from the sound generator outlet so that the acoustic waves received by the receiving transducer pass through a portion of the fluid. The electrical signals generated by the transmitting transducer and the receiving transducer are processed to obtain the impulse response of these electrical signals, and the point of maximum value is determined. This point of maximum value corresponds to the arrival time of the acoustic waves at the receiving location. The transit time determination may be used to calculate the fluid temperature or other parameters. The pneumatic sound generator is driven by a compressed air source so that the generator is automatically purged of any contaminants in the process of generating the random acoustic noise.

Method and apparatus for measuring acoustic wave velocity using impulse response

Instrumentation based on acoustic principles is finding widespread use in utility boiler applications. This paper describes how acoustic systems are currently being used to measure volumetric flow rate in large ducts and stacks for continuous emission monitoring system (CEMS) applications as well as for the measurement of high‐temperature flue gases and boiler control. Acoustic pyrometry is a useful tool for the measurement of gas temperatures in the furnace and superheater regions in boilers. Results have shown that acoustic pyrometry is easy to apply, accurate, and noninvasive. Gas temperature measurements are provided and displayed on a continuous real‐time basis for single path volumes in various furnace regions and for multiple path arrays in the furnace exit gas plane. The determination and presentation of isothermal maps of gas temperature provide a new tool for operation and maintenance diagnostics, not achievable by any other currently known method. Acoustic pyrometers are now being used to help identify and correct burner problems, slagging problems, and furnace overheating before these conditions can adversely affect operations.

John A. Kleppe

Papers

Method and apparatus for measuring acoustic wave velocity using impulse response

Advances in acoustic pyrometry.

Self-purging pneumatic acoustic generator