DE60105582T2 - Verfahren zum abkapseln von fluid in erdöllagerstätten - Google Patents
Verfahren zum abkapseln von fluid in erdöllagerstätten Download PDFInfo
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/001—Cooling arrangements
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/04—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/005—Waste disposal systems
- E21B41/0057—Disposal of a fluid by injection into a subterranean formation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
- E21B43/247—Combustion in situ in association with fracturing processes or crevice forming processes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
- Y02C20/00—Capture or disposal of greenhouse gases
- Y02C20/40—Capture or disposal of greenhouse gases of CO2
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/50—Improvements relating to the production of bulk chemicals
- Y02P20/582—Recycling of unreacted starting or intermediate materials
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10S48/00—Gas: heating and illuminating
- Y10S48/06—Underground gasification of coal
Description
- Die Erfindung bezieht sich auf ein Verfahren zum Sequestrieren eines Fluids innerhalb einer Kohlenwasserstoffe enthaltenden Formation.
- Kohlendioxid wird durch Energieerzeugungsprozesse und Verbrennungsprozesse gebildet. Der Großteil des so produzierten Kohlendioxids wird in die Atmosphäre entlassen, was bei Umweltschützern Bedenken hervorruft. Die Nettofreisetzung von Kohlendioxid an die Atmosphäre kann durch Verwenden des produzierten Kohlendioxids und/oder durch Lagern oder Sequestrieren von Kohlendioxid, beispielsweise innerhalb einer unterirdischen Kohlenwasserstoffe enthaltenden Formation, verringert werden.
- Ein Verfahren zum Sequestrieren von Kohlendioxid innerhalb einer unterirdischen Kohlenwasserstoffe enthaltenden Formation ist in US-A-5,566,756 beschrieben. Hierin wird beschrieben, daß in einer idealen Situation die unterirdische Kohlenwasserstoffe enthaltende Formation einheitlich ist, was bedeutet, daß eine Kohlendioxidkonzentrationsfront sich von einer Injektionsbohrung in der Formation radial nach außen bewegen wird. Gemäß US-A-5,566,756 gibt es jedoch sehr wenige Formationen, welche eine derartige Einheitlichkeit zeigen.
- In der US-Patentschrift 4,787,452 ist eine Reinjektion von feinen Teilchen in eine mit Dampf geflutete ölhältige Formation beschrieben. Der Artikel von C. W. Byrer "Appalachian coals, potential reservoirs for sequestering CO2..." in den Proceedings des International Coalbed Symposium vom 3. Mai 1999 beschreibt ein Verfahren zur CO2-Sequestrierung in Kohlebetten, aus welchen adsorbiertes Methan entfernt wurde.
- Es wurde nun festgestellt, daß eine verbesserte einheitliche, unterirdische Kohlenwasserstoffe enthaltende Formation, welche zum Darin-Sequestrieren von Fluiden geeignet ist, durch Unterwerfen der Formation unter eine in situ-Wärmebehandlung erhalten werden kann. Die so erhaltene Kohlenwasserstoffformation weist eine hohe Permeabilität und eine hohe Adsorptionskapazität auf. Die bevorzugte in situ-Wärmebehandlung kann Bedingungen der Pyrolyse und Bedingungen der Synthesegasbildung umfassen. Es ist ein zusätzlicher Vorteil, daß die so aus der Kohlenwasserstoffe enthaltenden Formation erhaltenen Kohlenwasserstofffluide und das Synthesegas wertvolle Produkte sind, sodaß diese als Energieressourcen als Einsatzmaterialien und als Verbraucherprodukte verwendet werden können.
- Die vorliegende Erfindung stellt daher ein Verfahren zum Abkapseln eines Fluids bereit, welches Verfahren ein in situ-Wärmebehandeln einer Kohlenwasserstoffe enthaltenden Formation und welche in situ-Wärmebehandlung ein Pyrolysieren von in der Formation vorliegenden Kohlenwasserstoffen, ein Sequestrieren des Fluids innerhalb der wärmebehandelten Formation umfaßt, wobei die Wärmebehandlung das Pyrolysieren von in der Formation vorhandenen Kohlenwasserstoffen mittels einer Mehrzahl von Wärmequellen in solcher Weise involviert, daß eine Überlagerung von aus den Wärmequellen produzierter Wärme eintritt, daß die wärmebehandelte Kohlenwasserstoffe enthaltende Formation wenigstens einen Abschnitt mit einer Permeabilität von wenigstens 100 Millidarcy aufweist und daß das sequestrierte Fluid an Kohlenwasserstoffe enthaltendes Material in der Formation adsorbiert wird.
- Die in situ-Wärmebehandlung dieser Erfindung ist im allgemeinen vorgesehen, um eine Verdampfung von Wasser, wenn dieses in der Formation vorhanden ist, und eine Umwandlung von in der Formation vorhandenen Kohlenwasserstoffen zu erzielen. In der Formation vorhandene Kohlenwasserstoffe können durch Pyrolyse umgewandelt werden, wodurch ein Kohlenwasserstofffluid produziert wird und wahlweise durch die Bildung von Synthesegas in Gegenwart eines Synthesegas generierenden Fluides. In einer bevorzugten Ausführungsform umfaßt die in situ-Wärmebehandlung die Verdampfung von Wasser, die Pyrolyse und die Synthesegasbildung in der angeführten Reihenfolge, unter der Voraussetzung, daß bei Fehlen von Wasser in der Formation die Verdampfung von Wasser ausgelassen werden kann.
- Vorzugsweise enthält die Kohlenwasserstoffe enthaltende Formation für die Verwendung in dieser Erfindung Kerogen. Kerogen setzt sich aus organischem Material zusammen, welches infolge eines Reifungsprozesses umgewandelt wurde. Kohlenwasserstoffe enthaltende Formationen, die Kerogen umfassen, sind z. B. Kohle enthaltende Formationen und Ölschiefer enthaltende Formationen. Alternativ können Kohlenwasserstoffe enthaltende Formationen behandelt werden, die kein Kerogen umfassen, z. B. Formationen, die schwere Kohlenwasserstoffe enthalten (z. B. Teersande).
- Kohlenwasserstoffe enthaltende Formationen können auf der Grundlage von Eigenschaften der Formation zur in situ-Wärmebehandlung ausgewählt werden, so daß diese zur Produktion von qualitativ hochwertigen Fluiden aus der Formation führt. Beispielsweise können Kohlenwasserstoffe enthaltende Formationen, die Kerogen umfassen, auf der Grundlage der Vitrinitreflexion des Kerogens für eine Behandlung bewertet oder ausgewählt werden. Die Vitrinitreflexion steht oft mit dem Verhältnis von elementarem Wasserstoff zu Kohlenstoff eines Kerogens und mit dem Verhältnis von elementarem Sauerstoff zu Kohlenstoff des Kerogens in Beziehung. Vorzugsweise liegt die Vitrinitreflexion im Bereich von 0,2% bis 3%, noch bevorzugter von 0,5% bis 2%. Solche Bereiche der Vitrinitreflexion neigen dazu, anzuzeigen, daß qualitativ relativ höherwertige Kohlenwasserstofffluide aus der Formation produziert werden können.
- Die Kohlenwasserstoffe enthaltende Formation kann auf der Grundlage des Gehalts an elementarem Wasserstoff des Kohlenwasserstoffs in der Kohlenwasserstoffe enthaltenden Formation für eine in situ-Wärmebehandlung ausgewählt werden. Beispielsweise kann typischerweise eine Kohlenwasserstoffe enthaltende Formation ausgewählt werden, die einen Kohlenwasserstoff mit einem Gehalt an elementarem Wasserstoff von größer als 2 Gew.-%, insbesondere größer als 3 Gew.-%, oder noch bevorzugter größer als 4 Gew.-%, gemessen auf trockener, aschefreier Basis, aufweist. Der Kohlenwasserstoff in der Kohlenwasserstoffe enthaltenden Formation weist vorzugsweise ein Verhältnis von elementarem Wasserstoff zu Kohlenstoff im Bereich von 0,5 bis 2, insbesondere von 0,70 bis 1,7 auf. Der Gehalt an elementarem Wasserstoff kann die Zusammensetzung der produzierten Kohlenwasserstofffluide signifikant beeinflussen, z. B. durch die Bildung von molekularem Wasserstoff.
- Die Kohlenwasserstoffe in der Formation können typischerweise einen Gewichtsprozentanteil an elementarem Sauerstoff von weniger als 20%, insbesondere weniger als 15% und noch bevorzugter weniger als 10%, gemessen auf trockener, aschefreier Basis, aufweisen. Typischerweise beträgt das Verhältnis von elementarem Sauerstoff zu Kohlenstoff weniger als 0,15. Auf diese Weise kann die Produktion von Kohlendioxid und weiteren Oxiden aus einem in situ-Umwandlungsvorgang von Kohlenwasserstoffe enthaltendem Material verringert werden. Häufig liegt das Verhältnis von elementarem Sauerstoff zu Kohlenstoff im Bereich von 0,03 bis 0,12.
- Das in situ-Erhitzen der Kohlenwasserstoffe enthaltenden Formation umfaßt im allgemeinen die Bereitstellung einer großen Energiemenge an Heizquellen, die innerhalb der Formation angeordnet sind. Kohlenwasserstoffe enthaltende Formationen können Wasser enthalten. Wasser, das in der Kohlenwasserstoffe enthaltenden Formation vorhanden ist, wird dazu neigen, die Energiemenge, die erforderlich ist, um die Kohlenwasserstoffe enthaltende Formation zu erhitzen, weiter zu erhöhen. Es können daher übermäßige Mengen an Wärme und/oder Zeit erforderlich sein, um eine Formation mit einem hohen Feuchtigkeitsgehalt zu erhitzen. Vorzugsweise beträgt der Wassergehalt der Kohlenwasserstoffe enthaltenden Formation weniger als 15 Gew.-%, noch bevorzugter weniger als 10%.
- Die Kohlenwasserstoffe enthaltende Formation oder der Abschnitt davon, der einer in situ-Wärmebehandlung unterzogen wird, kann eine Breite von z. B. wenigstens 0,5 m oder wenigstens 1,5 m oder wenigstens 2,4 m oder sogar wenigstens 3,0 m aufweisen. Die Breite kann bis zu 100 m oder bis zu 1000 m oder sogar bis zu 2000 m oder mehr betragen. Die Kohlenwasserstoffe enthaltende Formation oder der Abschnitt davon, der der in situ-Wärmebehandlung unterzogen wird, kann eine Schichtdicke von z. B. wenigstens 2 m, noch typischer im Bereich von 4 m bis 100 m und noch typischer von 6 m bis 60 m aufweisen. Die überlagernden Schichten der Kohlenwasserstoffe enthaltenden Formation können eine Dicke von z. B. wenigstens 10 m, noch typischer im Bereich von 20 m bis 800 m oder bis zu 1000 m oder mehr aufweisen.
- Die Kohlenwasserstoffe enthaltende Formation kann gemäß Verfahren nach dem Stand der Technik auf eine geeignte Temperatur erhitzt werden, indem eine oder mehrere in Heizbohrungen angeordnete Wärmequellen verwendet werden.
- Die Heizbohrungen können in der Nähe der oder vorzugsweise in der Kohlenwasserstoffe enthaltenden Formation angeordnet sein. Vorzugsweise wird eine Vielzahl von Wärmequellen verwendet, so daß eine große (ein großer Abschnitt einer) Kohlenwasserstoffe enthaltende(n) Formation erhitzt werden kann, und vorzugsweise derart, daß eine Überlagerung (Überlappung) der von den Wärmequellen erzeugten Hitze erfolgt. Eine Überlagerung von Hitze kann die Zeit verringern, die erforderlich ist, um die gewünschte Temperatur zu erreichen. Eine Überlagerung von Hitze kann einen relativ großen Abstand zwischen benachbarten Wärmequellen erlauben, was wiederum gewünschtenfalls für eine relativ langsame Aufheizgeschwindigkeit der Kohlenwasserstoffe enthaltenden Formation sorgt. Eine Überlagerung von Hitze wird auch für eine gleichmäßige Erhitzung sorgen, so daß die Temperaturen geregelt werden können, um Fluide gleichmäßig und mit den wünschenswerten Eigenschaften überall in einer (einem) großen (Abschnitt einer) Kohlenwasserstoffe enthaltenden Formation zu erzeugen.
- Der Abstand zwischen Wärmequellen kann typischerweise im Bereich von 5 m bis 20 m, vorzugsweise von 8 m bis 12 m liegen. Eine Anordnung im wesentlichen äquidistanter Wärmequellen in einem dreieckigen Muster wird bevorzugt, da dies ein gleichförmigeres Erhitzen der Formation im Vergleich mit anderen Mustern wie z. B. Sechsecken gewährleistet. Zusätzlich neigt ein dreieckiges Muster im Vergleich mit anderen Mustern wie Sechsecken bei der gleichen Flächendichte von Heizeinrichtungen dazu, ein schnelleres Aufheizen auf eine ausgewählte Temperatur zu gewährleisten.
- Es kann eine beliebige herkömmliche Wärmequelle angewendet werden. Es wird bevorzugt, Wärmequellen anzuwenden, die für eine Wärmeleitung geeignet sind, z. B. jede beliebige Art von elektrischer Heizeinrichtung oder jede beliebige Art von Combustor-Heizeinrichtung. Weniger bevorzugt sind Wärmequellen, die Radiofrequenzerhitzung anwenden. Beispiele von in situ-Verfahren, worin Untertage Heizeinrichtungen verwendet werden, sind in US-A-2,634,961, US-A-2,732,195, US-A-2,780,450, US-A-2,789,805, US-A-2,923,535 und US-A-4,886,118 beschrieben. Die Lehre dieser Dokumente ist bei der Durchführung der vorliegenden Erfindung allgemein anwendbar.
- Da die Permeabilität und/oder Porosität in der erhitzten Formation relativ schnell erhöht werden, können produzierte Dämpfe mit relativ geringem Druckunterschied über beträchtliche Distanzen durch die Formation strömen. Zunahmen der Durchlässigkeit resultieren aus einer Abnahme an Masse des erhitzten Abschnitts auf Grund des Verdampfens von Wasser, der Entfernung von Kohlenwasserstoffen und/oder der Erzeugung von Rissen. Für die Gewinnung der Kohlenwasserstofffluide und weiterer Fluide können Produktionsbohrungen vorgesehen sein. Fluid, das in der Kohlenwasserstoffe enthaltenden Formation gebildet wird, kann als Dampf eine beträchtliche Distanz durch die Kohlenwasserstoff enthaltende Formation zurücklegen. Solch eine beträchtliche Distanz kann z. B. 50 20 m bis 1000 m umfassen. Der Dampf kann auf Grund der Permeabilität des erhitzten Abschnitts der Formation einen relativ geringen Druckabfall über die beträchtliche Distanz aufweisen. Auf Grund einer solchen Permeabilität kann eine Produktionsbohrung nur in jeder zweiten Wärmequelleneinheit, oder in jeder dritten, vierten, fünften oder sechsten Wärmequelleneinheit, von denen eine jede mehrere Heizbohrungen, z. B. zwei, drei oder sechs umfassen kann, vorgesehen sein. Die Produktionsbohrungen können ausgekleidete Schächte sein, die ein Produktionssieb oder perforierte Auskleidungen aufweisen können. Zusätzlich können die Produktionsbohrungen von Sand oder Kies umgeben sein, um ein Verstopfen von Sieben zu minimieren.
- Zusätzlich können Wasserpumpbohrungen oder Vakuumbohrungen eingerichtet werden, um flüssiges Wasser aus der Kohlenwasserstoffe enthaltenden Formation zu entfernen. Beispielsweise können mehrere Wasserbohrungen die gesamte oder den Abschnitt der Formation, die erhitzt werden soll, umgeben.
- Wasser kann aus der Kohlenwasserstoffe enthaltenden Formation bei verhältnismäßig niedrigen Temperaturen beispielsweise bei Temperaturen über 50°C, häufig bis zu 250°C, typischerweise im Bereich von 80°C bis 220°C verdampft werden.
- Das als Ergebnis der Pyrolyse produzierte Kohlenwasserstofffluid ist ein Material, das in seiner Molekularstruktur Kohlenstoff und Wasserstoff enthält. Es kann auch andere Elemente wie Stickstoff, Sauerstoff und Schwefel umfassen.
- Die Kohlenwasserstoffe enthaltende Formation kann auf eine Temperatur erhitzt werden, bei der Pyrolyse stattfinden kann. Der Temperaturbereich für die Pyrolyse kann Temperaturen bis zu beispielsweise 900°C umfassen. Ein Großteil von Kohlenwasserstofffluiden kann innerhalb eines Pyrolysetemperaturbereiches von 250°C bis 400°C, bevorzugter im Bereich von 260°C bis 375°C produziert werden. Eine Temperatur, die ausreichend ist, um schwere Kohlenwasserstoffe in einer Kohlenwasserstoffe enthaltenden Formation mit relativ geringer Permeabilität zu pyrolysieren, kann innerhalb eines Bereiches von 270°C bis 375°C liegen. Bei weiteren Ausführungsformen kann eine Temperatur, die ausreichend ist, um schwere Kohlenwasserstoffe zu pyrolysieren, innerhalb eines Bereiches von 300°C bis 375°C liegen. Wenn eine Kohlenwasserstoffe enthaltende Formation über den gesamten Pyrolysetemperaturbereich erhitzt wird, kann die Formation in Richtung der Obergrenze des Pyrolysetemperaturbereiches nur geringe Mengen an Wasserstoff fördern. Nachdem der verfügbare Wasserstoff aufgebraucht ist, kann eine geringe Kohlenwasserstoffproduktion aus der Formation erfolgen.
- Vorzugsweise werden die zur Pyrolyse vorgesehene Kohlenwasserstoffe enthaltenden Formation oder die Abschnitte davon bei einer niedrigen Aufheizgeschwindigkeit erhitzt. Im allgemeinen wird die Aufheizgeschwindigkeit höchstens 50°C/Tag betragen. Typischerweise beträgt die Aufheizgeschwindigkeit weniger als 10°C/Tag, noch typischer weniger als 3°C/Tag, insbesondere weniger als 0,7°C Tag. Häufig wird die Aufheizgeschwindigkeit mehr als 0,01°C/Tag betragen, insbesondere mehr als 0,1°C/Tag. Derart niedrige Aufheizgeschwindigkeiten werden insbesondere im Pyrolysetemperaturbereich angewendet. Noch spezieller können erhitzte Abschnitte der Kohlenwasserstoffe enthaltenden Formation mit einer solchen Geschwindigkeit für eine Zeitdauer von mehr als 50% der Zeit erhitzt werden, die erforderlich ist, um den Pyrolysetemperaturbereich zu überspannen, vorzugsweise mehr als 75% der Zeit, die er forderlich ist, um den Pyrolysetemperaturbereich zu überspannen, oder noch bevorzugter mehr als 90% der Zeit, die erforderlich ist, um den Pyrolysetemperaturbereich zu überspannen.
- Die Geschwindigkeit, mit der die Kohlenwasserstoffe enthaltende Formation erhitzt wird, kann die Quantität und die Qualität der aus der Kohlenwasserstoffe enthaltenden Formation produzierten Kohlenwasserstofffluide beeinflussen. Zum Beispiel kann das Aufheizen mit hohen Aufheizgeschwindigkeiten eine größere Quantität an Fluiden aus der Kohlenwasserstoffe enthaltenden Formation fördern. Die Produkte solcher Verfahren können jedoch eine deutlich geringere Qualität aufweisen, als wenn beim Aufheizen niedrigere Aufheizgeschwindigkeiten verwendet werden. Ferner sorgt die Regelung der Aufheizgeschwindigkeit mit weniger als 3°C/Tag im allgemeinen für eine bessere Einheitlichkeit der Temperatur innerhalb der Kohlenwasserstoffe enthaltenden Formation.
- Das Erhitzen einer Kohlenwasserstoffe enthaltenden Formation auf den Pyrolysetemperaturbereich kann erfolgen, bevor innerhalb der Kohlenwasserstoffe enthaltenden Formation eine wesentliche Permeabilität erzeugt wurde. Ein anfängliches Fehlen von Permeabilität kann den Transport der erzeugten Fluide aus einer Pyrolysezone innerhalb der Formation verhindern. Auf diese Art und Weise kann, während zu Beginn Hitze von der Wärmequelle an die Kohlenwasserstoffe enthaltende Formation übertragen wird, der Fluiddruck in der Kohlenwasserstoffe enthaltenden Formation in der Nähe der Wärmequelle ansteigen.
- Der durch Expansion der in der Formation erzeugten Kohlenwasserstofffluide oder anderer Fluide erzeugte Druck kann zu Beginn ansteigen, da ein offener Pfad zu der Produktionsbohrung oder irgendeine andere Drucksenke in der Formation allenfalls noch nicht bestehen. Zusätzlich kann der Fluiddruck den lithostatischen Druck überschreiten, so daß sich in der Kohlenwasserstoffe enthaltenden Formation von den Wärmequellen zu den Produktionsboh rungen Risse bilden können. Die Bildung von Rissen innerhalb des erhitzten Abschnitts reduziert dann auf Grund der Produktion von Kohlenwasserstofffluiden durch die Produktionsbohrungen den Druck.
- Um den Druck innerhalb der Kohlenwasserstoffe enthaltenden Formation während der Produktion von Kohlenwasserstofffluiden aufrecht zu erhalten, kann an der Produktionsbohrung ein Gegendruck aufrecht erhalten werden. Der Druck kann mit Hilfe von Ventilen und/oder durch Injizieren von Gasen, z. B. Wasserstoff, Kohlendioxid, Kohlenmonoxid, Stickstoff oder Methan, oder Wasser oder Wasserdampf in die Kohlenwasserstoffe enthaltende Formation geregelt werden. Das Injizieren von Wasserstoff wird besonders bevorzugt.
- Die Ventile können so ausgebildet sein, daß sie den Druck innerhalb der Kohlenwasserstoffe enthaltenden Formation aurechterhalten, ändern und/oder regeln. Zum Beispiel können Wärmequellen, die innerhalb der Kohlenwasserstoffe enthaltenden Formation angeordnet sind, mit einem Ventil gekoppelt werden. Das Ventil kann so ausgebildet sein, daß es Fluid aus der Formation durch die Wärmequelle freisetzt, oder um ein Gas in die Kohlenwasserstoffe enthaltende Formation zu injizieren. Alternativ kann ein Druckventil mit den Produktionsbohrungen gekoppelt sein. Fluide, die von den Ventilen freigesetzt werden, können gesammelt und für eine weitere Verarbeitung und/oder Behandlung zu einer Einheit an der Oberfläche befördert werden.
- Der Druck kann während der Pyrolyse und während der Produktion des Kohlenwasserstofffluids aus der Formation geregelt werden. Typischerweise wird ein Druck von wenigstens 1,5 bar angelegt, noch typischer wenigstens 1,6 bar, insbesondere wenigstens 1,8 bar. Häufig kann, wenn die Pyrolysetemperatur wenigstens 300°C beträgt, ein Druck von wenigstens 1,6 bar angelegt werden, und unterhalb von 300°C kann ein Druck von wenigstens 1,8 bar angelegt werden. Die Druckobergrenze kann durch die Festigkeit und das Gewicht der überlagernden Schichten bestimmt sein. Häufig beträgt der Druck unter Praxisbedingungen weniger als 70 bar, häufiger weniger als 60 bar oder sogar weniger als 50 bar. Der Druck kann vorteilhafterweise innerhalb eines Bereiches von 2 bar bis 18 bar oder 20 bar, oder alternativ innerhalb eines Bereiches von 20 bar bis 36 bar geregelt werden.
- Sofern nicht anders angegeben, wird der Ausdruck "Druck" hierin als auf Absolutdruck bezogen betrachtet. Der Druck, der während der Produktion von Kohlenwasserstofffluid aus der Formation oder während der Produktion von Synthesegas herrscht, wird als in einer Produktionsbohrung in direkter Nähe zu dem relevanten Abschnitt der Formation, wo die Pyrolyse oder die Produktion von Synthesegas stattfindet, gemessen, angesehen.
- In einer bevorzugten Ausführungsform wird ein Wasserstoffpartialdruck aufrecht erhalten. Typischerweise beträgt der Partialdruck wenigstens 0,2 bar, geeigneterweise wenigstens 0,4 bar, beispielsweise bis zu 35 bar oder sogar bis zu 50 bar, noch typischer im Bereich von 0,6 bar bis 20 bar, im speziellen im Bereich von 1 bar bis 10 bar, noch spezieller im Bereich von 5 bar bis 7 bar. Das Aufrechterhalten eines Wasserstoffpartialdruckes innerhalb der Formation erhöht insbesondere die API-Schwerkraft der produzierten Kohlenwasserstofffluide und verringert die Produktion von langkettigen Kohlenwasserstofffluiden.
- Wenigstens 20%, typischerweise wenigstens 25%, vorzugsweise wenigstens 35% des anfänglichen Gesamtgehaltes an organischem Kohlenstoff der Kohlenwasserstoffe enthaltenden Formation oder des Abschnitts davon, der der Pyrolyse unterzogen wird, kann zu Kohlenwasserstofffluiden umgewandelt werden. In der Praxis können häufig höchstens 90% des Gesamtgehaltes an organischem Kohlenstoff der Kohlenwasserstoffe enthaltenden Formation oder des Abschnitts davon, der einer Pyrolyse unterzogen wird, in Kohlenwasserstofffluide umgewandelt werden, häufiger können dies höchstens 80% oder höchstens 70% oder höchstens 60% sein.
- Die Pyrolyse und die Synthesegasbildung liefern eine hohe, gleichförmige Permeabilität überall in der Kohlenwasserstoffe enthaltenden Formation oder dem behandelten Abschnitt hiervon. Eine hohe, gleichförmige Permeabilität erlaubt die Bildung von Synthesegas mit niedrigeren Injektionskosten und ohne Abtasten oder Umgehen großer Teilabschnitte der Formation. Der Abschnitt weist auch einen großen Oberflächenbereich und/oder einen großen Oberflächenbereich/Volumen auf. Der große Oberflächenbereich kann zulassen, daß Synthesegas generierende Reaktionen im wesentlichen bei Gleichgewichtsbedingungen während der Erzeugung von Synthesegas erfolgen. Im Vergleich mit einer Erzeugung von Synthesegas in einer Kohlenwasserstoffe enthaltenden Formation, die keiner Pyrolyse unterzogen wurde, kann die relativ hohe, gleichförmige Permeabilität zu einer relativ hohen Gewinnungseffizienz an Synthesegas führen.
- Die Pyrolyse von wenigstens etwas Kohlenwasserstoffe enthaltendem Material kann bei einigen Ausführungsformen 20% des ursprünglich verfügbaren Kohlenstoffes umwandeln. Die Synthesegaserzeugung kann wenigstens (zusätzliche) 10% und typischerweise bis zu (zusätzliche) 70% des anfänglich verfügbaren Kohlenstoffes umwandeln. Auf diese Weise kann die in situ-Synthesegaserzeugung aus einer Kohlenwasserstoffe enthaltenden Formation, zusätzlich zur Pyrolyse, die Umwandlung größerer Mengen an anfänglich in dem Abschnitt verfügbarem Kohlenstoff erlauben.
- Das Synthesegas kann aus der Formation vor, gemeinsam mit oder nach der Produktion von Kohlenwasserstofffluid aus der Formation produziert werden. Das Synthesegas kann, obwohl es im allgemeinen als ein Gemisch aus Wasserstoff (H2) und Kohlenmonoxid (CO) defi niert ist, zusätzliche Komponenten wie Wasser, Kohlendioxid (CO2), Methan und andere Gase umfassen.
- Die Synthesegaserzeugung kann begonnen werden, bevor und/oder nachdem die Kohlenwasserstofffluidproduktion auf ein unwirtschaftliches Niveau abgesunken ist. Auf diese Weise kann Wärme, die für die Pyrolyse bereitgestellt wird, auch verwendet werden, um Synthesegas zu erzeugen. Wenn z. B. ein Abschnitt der Formation nach der Pyrolyse 375°C aufweist, so ist im allgemeinen weniger zusätzliche Hitze erforderlich, um einen solchen Abschnitt auf eine Temperatur zu erhitzen, die ausreichend ist, um eine Synthesegaserzeugung zu unterstützen. In bestimmten Fällen kann Hitze von einer oder mehreren Wärmequellen bereitgestellt werden, um die Formation auf eine Temperatur zu erhitzen, die eine Synthesegaserzeugung erlaubt, z. B. im Bereich von 400°C bis 1200°C oder höher. Am oberen Ende des Temperaturbereiches kann das erzeugte Synthesegas hauptsächlich H2 und CO umfassen, z. B. in einem Molverhältnis von 1 : 1. Am unteren Ende dieses Temperaturbereiches kann das erzeugte Synthesegas ein höheres H2-zu-CO-Verhältnis aufweisen.
- Heizbohrungen, Wärmequellen und Produktionsbohrungen innerhalb der Formation zur Verdampfung von Wasser oder zur Pyrolyse und zur Produktion von Kohlenwasserstofffluiden aus der Formation können während der Synthesegaserzeugung als eine Injektionsbohrung, um Synthesegas generierendes Fluid einzuleiten, als eine Produktionsbohrung, oder als eine Wärmequelle, um die Formation zu erhitzen, verwendet werden. Wärmequellen für die Synthesegaserzeugung können jede beliebige der hierin vorstehend beschriebenen Wärmequellen umfassen. Alternativ kann das Erhitzen umfassen, daß Wärme von einem Wärmeübertragungsfluid, z. B. Wasserdampf oder Verbrennungsprodukten aus einem Brenner, übertragen wird, das innerhalb einer Vielzahl von Bohrlöchern innerhalb der Formation strömt.
- Ein Synthesegas generierendes Fluid, z. B. flüssiges Wasser, Wasserdampf, Kohlendioxid, Luft, Sauerstoff, Kohlenwasserstoffe und Gemische daraus, kann der Formation bereitgestellt werden. Zum Beispiel kann das Synthesegas generierende Fluidgemisch Wasserdampf und Sauerstoff umfassen. Das Synthesegas generierende Fluid kann wäßriges Fluid umfassen, das durch Pyrolyse von Kohlenwasserstoffe enthaltendem Material innerhalb eines weiteren Abschnitts der Formation erzeugt wurde. Die Bereitstellung eines Synthesegas generierenden Fluids kann alternativ umfassen, daß ein Wasserspiegel der Formation angehoben wird, so daß Wasser in diese strömen kann. Synthesegas generierendes Fluid kann auch durch eine Injektionsbohrung bereitgestellt werden. Das Synthesegas generierende Fluid wird im allgemeinen mit dem Kohlenwasserstoff in der Formation reagieren, um H2, Wasser (als Flüssigkeit oder als Dampf), CO2 und/oder CO zu bilden.
- Kohlendioxid kann von dem Synthesegas abgetrennt werden und kann mit dem Synthesegas generierenden Fluid wieder in die Formation injiziert werden. Durch- eine Verschiebung der vorherrschenden chemischen Gleichgewichtsreaktionen kann dem Synthesegas generierenden Fluid zugesetztes Kohlendioxid eine weitere Produktion von Kohlendioxid während der Synthesegaserzeugung wesentlich hemmen. Das Kohlendioxid kann auch mit Kohlenstoff in der Formation reagieren und Kohlenmonoxid bilden.
- Kohlenwasserstoffe wie Ethan können dem Synthesegas generierenden Fluid zugesetzt werden. Wenn die Kohlenwasserstoffe in die Formation eingeleitet werden, können sie cracken und Wasserstoff und/oder Methan bilden. Das Vorhandensein von Methan in dem produzierten Synthesegas kann dessen Heizwert erhöhen.
- Synthesegas generierende Reaktionen sind typischerweise endotherme Reaktionen. Während der Synthesegaserzeugung kann der Formation Hitze zugeführt werden, um die Temperatur der Formation auf einem gewünschten Niveau zu halten. Hitze kann von Wärmequellen und/oder aus der Einleitung von Synthesegas generierendem Fluid, das eine höhere Temperatur aufweist als die Temperatur der Formation, zugeführt werden. Als Alternative kann dem Synthesegas generierendem Fluid ein Oxidationsmittel, z. B. Luft, mit Sauerstoff angereicherte Luft, Sauerstoff, Wasserstoffperoxid, andere oxidierende Fluide, oder Kombinationen daraus, zugesetzt werden. Das Oxidationsmittel kann mit Kohlenstoff innerhalb der Formation reagieren und Hitze erzeugen, und dies resultiert in der Produktion von CO2 und/oder CO. In einer bevorzugten Ausführungsform werden der Formation Sauerstoff und Wasser (oder Wasserdampf) z. B. in einem Molverhältnis von 1 : 2 bis 1 : 10, vorzugsweise von 1 : 3 bis 1 : 7, z. B. 1 : 4, bereitgestellt.
- Die Kohlenwasserstoffe enthaltende Formation kann während der Synthesegaserzeugung bei einem relativ hohen Druck gehalten werden. Synthesegas kann in einem weiten Druckbereich, z. B. zwischen 1 bar und 100 bar, typischer zwischen 2 bar und 80 bar, insbesondere zwischen 5 bar und 60 bar erzeugt werden. Hohe Betriebsdrücke können zu einer erhöhten Produktion von H2 führen. Hohe Betriebsdrücke können die Erzeugung von Elektrizität ermöglichen, indem produziertes Synthesegas durch eine Turbine geleitet wird, und sie können kleinere Sammelleitungen für den Transport von produziertem Synthesegas ermöglichen.
- Das Synthesegas kann in einem weiten Temperaturbereich wie z. B. von 400°C bis 1.200°C, typischer von 600°C bis 1.000°C, erzeugt werden. Bei einer relativ niedrigen Synthesegaserzeugungstemperatur kann ein Synthesegas produziert werden, das ein hohes H2-zu-CO-Verhältnis aufweist. Eine relativ hohe Temperatur der Formation kann ein Synthesegas produzieren, das ein H2-zu-CO-Verhältnis aufweist, das sich 1 nähert, und der Strom kann hauptsächlich (und in einigen Fällen im wesentlichen nur) H2 und CO umfassen. Bei einer Formationstemperatur von ungefähr 700°C kann die Formation ein Synthesegas mit einem H2-zu-CO-Verhältnis von 2 produzieren. Typischerweise kann Synthesegas erzeugt werden, das ein H2-zu-CO-Molverhältnis im Bereich von 1 : 4 bis 8 : 1, typischer im Bereich von 1 : 2 bis 4 : 1, insbesondere im Bereich von 1 : 1 bis 2,5 : 1 aufweist. Bestimmte Ausführungsformen können umfassen, daß ein erstes Synthesegas mit einem zweiten Synthesegas vermischt wird, um ein Synthesegas mit einer gewünschten Zusammensetzung zu produzieren. Das erste und das zweite Synthesegas können aus verschiedenen Abschnitten der Formation produziert werden.
- Man kann die Kohlenwasserstoffe enthaltende Formation oder den Abschnitt davon, der einer in situ-Wärmebehandlung unterzogen wurde, abkühlen lassen oder abkühlen, so daß eine abgekühlte erschöpfte Formation ausgebildet wird. Nach der in situ-Wärmebehandlung wird ein Fluid innerhalb der Formation sequestriert. Fluide, welche sequestriert werden können, umfassen eines oder mehrere beispielsweise von Stickoxiden, Schwefeloxiden und Kohlenstoffoxiden, insbesondere Kohlendioxid.
- Um eine bedeutende Menge an Fluid innerhalb der Formation zu speichern, wird es oft notwendig sein, daß die Temperatur der Formation weniger als 100°C, z. B. bis hinunter auf 20°C, beträgt. Beispielsweise kann eine höhere Menge an Fluid in der Formation bei einer niedrigen Temperatur adsorbiert werden. Zusätzlich kann das Abkühlen der Formation diese verstärken. Wasser kann in die Formation eingeleitet werden, um Wasserdampf zu erzeugen und die Temperatur der Formation zu verringern. Der Wasserdampf kann aus der Formation entfernt werden. Der Wasserdampf kann für verschiedene Zwecke genutzt werden, z. B., um einen weiteren Abschnitt der Formation zu erhitzen, um Synthesegas in einem benachbarten Abschnitt der Formation zu erzeugen, oder als Dampfeinpressung in einer Erdöllagerstätte.
- Als Folge der in situ-Wärmebehandlung erhöht sich die Permeabilität der Kohlenwasserstoffe enthaltenden Formation. Der Anstieg in der Permeabilität kann um einen Faktor von mehr als 1.000, 10.000 oder sogar 100.000 sein. Während beispielsweise die Permeabilität einer unbehandelten Kohlenwasserstoffe enthaltenden Formation 0,1 Millidarcy (9,9 × 10–17 m2) oder weniger sein kann, kann die Permeabilität als Ergebnis der in situ-Wärmebehandlung ansteigen, beispielsweise auf wenigstens 10 Millidarcy, typischerweise auf wenigstens 100 Millidarcy, in noch typischerer Weise auf wenigstens 1 Darcy, vorzugsweise auf wenigstens 10 Darcy, stärker bevorzugt auf wenigstens 20 Darcy, insbesondere auf wenigstens 50 Darcy. In der Praxis wird die Permeabilität häufig unter 100 Darcy bleiben.
- Ein einheitliches Erhitzen der Kohlenwasserstoffe enthaltenden Formation während der in situ-Wärmebehandlung wird bevorzugt, da dies im allgemeinen zu einem gleichförmigeren Anstieg in der Permeabilität führt. In dieser Hinsicht sind ein Erhitzen durch Leiten und insbesondere durch Überlagerung (z. B. Überlappen) von Hitze von einer oder mehreren Wärmequellen bevorzugte Wege des Erhitzens. Im quantitativen Sinn wird der Ausdruck "gleichförmige Permeabilität" hierin so verstanden, daß die Permeabilität der (des) in situ-wärmebehandelten (Abschnitts der) Formation um nicht mehr als einen Faktor von 10 variiert, d. h., daß die bewertete Permeabilität von jedem beliebigen ausgewählten Teilabschnitt in der Formation um nicht mehr als einen Faktor von 10 von der bewerteten durchschnittlichen Permeabilität eines derartigen ausgewählten Abschnitts variiert.
- Die Entfernung von Kohlenwasserstoffen aus einer Kohlenwasserstoffe enthaltenden Formation, wie sie in jeder beliebigen der vorstehenden Ausführungsformen beschrieben ist, läuft im allgemeinen auch im mikroskopischen Maßstab ab. Kohlenwasserstoffe können aus Mikroporen innerhalb des Abschnitts infolge des Erhitzens entfernt werden. Mikroporen können die Poren mit einer Querschnittsdimension von weniger als 1.000 Å sein. Das in situ-Erhitzen der Kohlenwasserstoffe enthaltenden Formation wie es in irgendeiner der vorstehenden Ausführungsformen be schrieben ist, kann somit auch die Porosität der Kohlenwasserstoffe enthaltenden Formation gleichmäßig erhöhen.
- Darüber hinaus sind die physikalischen Eigenschaften der Kohlenwasserstoffe enthaltenden Formation nach der in situ-Wärmebehandlung, insbesondere nach der Pyrolyse, im allgemeinen jenen eines porösen Betts ähnlich. Beispielsweise kann die Kohlenwasserstoffe enthaltende Formation nach der Wärmebehandlung Teilchen mit Größen von mehreren Millimetern umfassen. Ein in einen pyrolysierten Abschnitt einer Kohlenwasserstoffe enthaltenden Formation injiziertes Gas kann leicht und gleichmäßig mit dem in der Formation verbliebenen Kohlenstoff und/oder den Kohlenwasserstoffen in Kontakt treten und die durch Erhitzen der Kohlenwasserstoffe produzierten Gase können eine signifikante Distanz innerhalb des erhitzten Abschnitts der Formation mit einem minimalen Druckverlust zurücklegen. Dies ist vorteilhaft, insbesondere wenn die Kohlenwasserstoffe enthaltende Formation zur Sequestrierung von Fluiden verwendet werden soll. Eine höhere Permeabilität führt im allgemeinen zu geringeren Kompressionskosten.
- Nachdem die Formation abgekühlt ist, kann Fluid in der Formation unter Druck gesetzt und sequestriert werden. Das Sequestrieren von Fluid innerhalb der Formation kann zu einer deutlichen Abnahme oder Eliminierung von Fluid, das auf Grund des Betriebes des vorliegenden in situ-Verfahrens in die Umwelt freigesetzt wird, führen.
- Das Fluid, das sequestriert werden soll, kann unter Druck in die abgekühlte erschöpfte Formation injiziert werden und auf Kohlenwasserstoffe enthaltendem Material in der Formation adsorbiert werden. Das Fluid kann vor der Injektion typischerweise auf einen Druck von wenigstens 2 bar, beispielsweise bis zu 100 bar oder sogar bis zu 120 bar, vorzugsweise im Bereich von 5 bar bis 50 bar unter Druck gesetzt werden. Ein Gegendruck kann in der Forma tion bis zum Maximum des Fluiddrucks aufrechterhalten werden, um die Absorption zu erleichtern. Das zu absorbierende Fluid kann Methan, sofern dieses vorhanden ist, aus der in situ-wärmebehandelten Formation verdrängen. Eine darauffolgende Zugabe von Wasser zur Formation kann eine Desorption von Kohlendioxid hemmen.
- Die aus der Kohlenwasserstoffe enthaltenden Formation erhaltenen Kohlenwasserstofffluide können als Energieressourcen, als Einsatzmaterialien und als Verbraucherprodukte verwendet werden. Die hierin beschriebenen Synthesegase können zu Kohlenwasserstoffen umgewandelt werden, welche Methanol umfassen, oder zu anderen Produkten wie Ammoniak. Das Synthesegas kann auch als Energiequelle verwendet werden.
- Die folgenden Beispiele veranschaulichen die Erfindung.
- Beispiel 1
- Kohlenwasserstofffluide wurden aus einer Kohle enthaltenden Formation durch in situ-Pyrolyse produziert. Die Kohle war eine einen hohen Gehalt an flüchtigen Bestandteilen aufweisende bituminöse "C"-Kohle mit einer Vitrinitreflexion von 0,54%, welche als Formationsschicht von etwa 4,9 m Dicke vorlag. Es wurden drei Wärmequellen in der Kohleformation in dreieckiger Konfiguration mit einem 2 m Abstand auf einer Seite angeordnet. Eine Produktionsbohrung wurde nahe dem Zentrum des Wärmequellenmusters und äquidistant von jeder der Wärmequellen angeordnet. Eine Spritzwand wurde um das Wärmequellenmuster und die Produktionsbohrung ausgebildet, um das Einströmen von Wasser in den Abschnitt der Formation, welcher einer Pyrolyse unterworfen wurde, zu verhindern. Temperaturbeobachtungsbohrungen wurden innerhalb der dreieckigen Konfiguration von Wärmequellen verteilt.
- Die Temperatur der Kohleformation innerhalb der dreieckigen Konfiguration wurde erhitzt, um eine Pyrolyse zu ermöglichen. Die Kohlenwasserstofffluide wurden bei 1 bar Druck in der Kohleformation innerhalb der dreieckigen Konfiguration gesammelt. Das bei 1 bar Druck erhaltene kondensierbare Kohlenwasserstoffprodukt enthielt etwa 2 Gew.-% an C25-Kohlenwasserstoffen, wogegen der Gehalt an C25-Kohlenwasserstoffen des kondensierbaren Kohlenwasserstoffprodukts, welches bei 8 bar Druck erhalten wurde, etwa 0,1 Gew.-% betrug.
- Es wurde ein Versuch mit der Formation durchgeführt, um die gleichförmige Permeabilität der Formation nach der Pyrolyse zu ermitteln. Zu diesem Zweck wurden 10 Minuten Pulse von CO2 in die Formation an der Produktionsbohrung injiziert und an jeder der Heizbohrungen produziert. Das CO2 erreichte jede der drei unterschiedlichen Heizbohrungen zu ungefähr dem gleichen Zeitpunkt. Die Ausbeute an CO2 aus jeder der drei verschiedenen Bohrungen war ebenfalls über die Zeit ungefähr gleich. Die Tatsache, daß die erste CO2-Ankunft nur ungefähr 18 Minuten nach Beginn des CO2-Pulses erfolgte, weist darauf hin, daß sich keine bevorzugten Pfade zwischen der Produktionsbohrung und den Heizbohrungen ausgebildet hatten. Die Ergebnisse zeigen, daß die Formation ein hohes Ausmaß an Gleichförmigkeit aufweist, da sie es einer Kohlendioxidkonzentrationsfront erlaubt, von der Injektionsbohrung radial nach außen in die Formation zu strömen.
- Die in situ-Permeabilität wurde unter Verwendung einer stationären Gasinjektion und von Druckgradientenmessungen ermittelt, nachdem die Pyrolyse- und Synthesegasbildungsschritte beendet waren. Die innerhalb des Heizeinrichtungsdreieckes gemessene Permeabilität variierte von 4,5 Darcy bis 39 Darcy, was darauf hinweist, daß die Permeabilität hoch und verhältnismäßig gleichförmig war. Die mittlere Permeabilität vor der Behandlung betrug nur 50 Millidarcy.
- Beispiel 2
- Proben von subbituminöser Kohle von Gillette, Wyoming, wurden Pyrolysebedingungen unterworfen. Die Proben der nicht pyrolysierten Kohle und der pyrolysierten Kohle wurden anschließend hinsichtlich ihrer Fähigkeit zur Adsorption von Kohlendioxid untersucht.
- Es wurde festgestellt, daß bei einem Druck von 25 bar und bei 25°C die unpyrolysierte Kohle 25,5 Standardkubikmeter pro Tonne (900 Standardkubikfuß pro Tonne) adsorbierte, wogegen die pyrolysierte Kohle 43,3 Standardkubikmeter pro Tonne (1.600 Standardkubikfuß pro Tonne) adsorbierte.
Claims (10)
- Verfahren zum Abkapseln eines Fluids, welches Verfahren ein in situ-Wärmebehandeln einer Kohlenwasserstoffe enthaltenden Formation und ein Sequestrieren des Fluids innerhalb der wärmebehandelten Formation umfaßt, dadurch gekennzeichnet, daß die in situ-Wärmebehandlung ein Pyrolysieren von in der Formation vorliegenden Kohlenwasserstoffen mittels einer Mehrzahl von Wärmequellen in solcher Weise involviert, daß eine Überlagerung von aus den Wärmequellen produzierter Wärme eintritt, daß die in situ wärmebehandelte Kohlenwasserstoffe enthaltende Formation wenigstens einen Abschnitt mit einer Permeabilität von wenigstens 100 Millidarcy aufweist und daß das sequestrierte Fluid an Kohlenwasserstoffe enthaltendes Material in der Formation adsorbiert wird.
- Verfahren nach Anspruch 1, worin die Kohlenwasserstoffe enthaltende Formation ein Kerogen, wie Kohle oder Ölschiefer, oder schwere Kohlenwasserstoffe wie einen Teersand umfaßt.
- Verfahren nach Anspruch 1 oder 2, worin das in situ-Erhitzen mittels einer Wärmequelle erzielt wird, die für ein Erhitzen durch Leitung geeignet ist.
- Verfahren nach einem der Ansprüche 1 bis 3, worin die in situ-Wärmebehandlung weiterhin eine Synthesegasbildung in Gegenwart eines Synthesegas generierenden Fluids umfaßt.
- Verfahren nach einem der Ansprüche 1 bis 4, worin das zu sequestrierende Fluid Kohlendioxid umfaßt.
- Verfahren nach einem der Ansprüche 1 bis 5, worin das Fluid bei einer Temperatur im Bereich von 0°C bis 100°C sequestriert wird.
- Verfahren nach einem der Ansprüche 1 bis 6, worin das zu sequestrierende Fluid auf einen Druck im Bereich von 2 bar bis 120 bar unter Druck gesetzt wird.
- Verfahren nach einem der Ansprüche 1 bis 7, worin die in situ-wärmebehandelte Kohlenwasserstoffe enthaltende Formation wenigstens einen Abschnitt mit einer im wesentlichen gleichförmigen Permeabilität von wenigstens 10 Darcy aufweist.
- Verfahren nach einem der vorstehenden Ansprüche, worin die wärmebehandelte Kohlenwasserstoffe enthaltende Formation Mikroporen mit einer Querschnittsabmessung von unter 1.000 Å umfaßt.
- Verfahren nach einem der vorstehenden Ansprüche, worin die wärmebehandelte Kohlenwasserstoffe enthaltende Formation Teilchen mit Größen von mehreren Millimetern umfaßt und physikalische Eigenschaften aufweist, die im wesentlichen denen eines porösen Bettes ähnlich sind.
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DE60105583T Expired - Lifetime DE60105583T2 (de) | 2000-04-24 | 2001-04-24 | Verfahren zur behandlug von erdöllagerstätten |
DE60105584T Expired - Lifetime DE60105584T2 (de) | 2000-04-24 | 2001-04-24 | In-situ-gewinnung von kohlenwasserstoffen aus einer kerogen enthaltenden formation |
DE60116616T Expired - Fee Related DE60116616T2 (de) | 2000-04-24 | 2001-04-24 | Vorrichtung und verfahren zur behandlung von erdöllagerstätten |
DE60105582T Expired - Lifetime DE60105582T2 (de) | 2000-04-24 | 2001-04-24 | Verfahren zum abkapseln von fluid in erdöllagerstätten |
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DE60121744T Expired - Lifetime DE60121744T2 (de) | 2000-04-24 | 2001-04-24 | Verfahren zur behandlung von erdöllagerstätten |
DE60105583T Expired - Lifetime DE60105583T2 (de) | 2000-04-24 | 2001-04-24 | Verfahren zur behandlug von erdöllagerstätten |
DE60105584T Expired - Lifetime DE60105584T2 (de) | 2000-04-24 | 2001-04-24 | In-situ-gewinnung von kohlenwasserstoffen aus einer kerogen enthaltenden formation |
DE60116616T Expired - Fee Related DE60116616T2 (de) | 2000-04-24 | 2001-04-24 | Vorrichtung und verfahren zur behandlung von erdöllagerstätten |
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US (88) | US6902004B2 (de) |
EP (6) | EP1276967B1 (de) |
CN (4) | CN1263938C (de) |
AT (5) | ATE276426T1 (de) |
AU (12) | AU5836701A (de) |
CA (14) | CA2669786C (de) |
DE (5) | DE60121744T2 (de) |
EA (5) | EA004549B1 (de) |
GB (1) | GB2379469B (de) |
IL (7) | IL152455A0 (de) |
MA (1) | MA26148A1 (de) |
MY (1) | MY129205A (de) |
NZ (8) | NZ522210A (de) |
TR (1) | TR200402725T4 (de) |
WO (8) | WO2001081716A2 (de) |
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- 2001-04-24 US US09/841,127 patent/US20020027001A1/en not_active Abandoned
- 2001-04-24 US US09/841,308 patent/US6729395B2/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,434 patent/US6722429B2/en not_active Expired - Lifetime
- 2001-04-24 CA CA002407026A patent/CA2407026A1/en not_active Abandoned
- 2001-04-24 US US09/841,284 patent/US6866097B2/en not_active Expired - Fee Related
- 2001-04-24 US US09/841,240 patent/US20020040780A1/en not_active Abandoned
- 2001-04-24 EA EA200201132A patent/EA004326B1/ru not_active IP Right Cessation
- 2001-04-24 AU AU2001260247A patent/AU2001260247A1/en not_active Abandoned
- 2001-04-24 CA CA2669559A patent/CA2669559C/en not_active Expired - Lifetime
- 2001-04-24 TR TR2004/02725T patent/TR200402725T4/xx unknown
- 2001-04-24 DE DE60116616T patent/DE60116616T2/de not_active Expired - Fee Related
- 2001-04-24 AU AU65902/01A patent/AU773413B2/en not_active Expired
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- 2001-04-24 EA EA200201127A patent/EA200201127A1/ru unknown
- 2001-04-24 US US09/841,488 patent/US6742589B2/en not_active Expired - Fee Related
- 2001-04-24 US US09/841,307 patent/US6789625B2/en not_active Expired - Lifetime
- 2001-04-24 AU AU6590301A patent/AU6590301A/xx active Pending
- 2001-04-24 CA CA002407404A patent/CA2407404A1/en not_active Abandoned
- 2001-04-24 CN CNB018113176A patent/CN1278016C/zh not_active Expired - Fee Related
- 2001-04-24 US US09/841,489 patent/US6712136B2/en not_active Expired - Lifetime
- 2001-04-24 EP EP01933885A patent/EP1276966A1/de not_active Withdrawn
- 2001-04-24 US US09/841,300 patent/US6966372B2/en not_active Expired - Fee Related
- 2001-04-24 AT AT01943286T patent/ATE276425T1/de not_active IP Right Cessation
- 2001-04-24 US US09/841,283 patent/US6729397B2/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,435 patent/US6739394B2/en not_active Expired - Fee Related
- 2001-04-24 IL IL15245501A patent/IL152455A0/xx unknown
- 2001-04-24 CA CA2670076A patent/CA2670076A1/en not_active Abandoned
- 2001-04-24 US US09/841,193 patent/US20020033253A1/en not_active Abandoned
- 2001-04-24 US US09/841,447 patent/US6910536B2/en not_active Expired - Lifetime
- 2001-04-24 IL IL15245801A patent/IL152458A0/xx unknown
- 2001-04-24 US US09/841,311 patent/US6732796B2/en not_active Expired - Fee Related
- 2001-04-24 US US09/841,291 patent/US6607033B2/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,303 patent/US6702016B2/en not_active Expired - Lifetime
- 2001-04-24 AT AT01927922T patent/ATE315715T1/de not_active IP Right Cessation
- 2001-04-24 US US09/841,061 patent/US6959761B2/en not_active Expired - Fee Related
- 2001-04-24 US US09/841,293 patent/US6725920B2/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,443 patent/US6588503B2/en not_active Expired - Fee Related
- 2001-04-24 US US09/841,304 patent/US6761216B2/en not_active Expired - Fee Related
- 2001-04-24 NZ NZ522214A patent/NZ522214A/en unknown
- 2001-04-24 DE DE60105582T patent/DE60105582T2/de not_active Expired - Lifetime
- 2001-04-24 CN CNB018101658A patent/CN1263939C/zh not_active Expired - Fee Related
- 2001-04-24 US US09/841,297 patent/US6591906B2/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,636 patent/US20020049360A1/en not_active Abandoned
- 2001-04-24 US US09/841,301 patent/US6948563B2/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,309 patent/US6742588B2/en not_active Expired - Fee Related
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- 2001-04-24 CA CA2670129A patent/CA2670129C/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,285 patent/US6820688B2/en not_active Expired - Fee Related
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- 2001-04-24 CA CA002407215A patent/CA2407215A1/en not_active Withdrawn
- 2001-04-24 US US09/841,501 patent/US6763886B2/en not_active Expired - Fee Related
- 2001-04-24 US US09/841,238 patent/US6769483B2/en not_active Expired - Fee Related
- 2001-04-24 US US09/841,437 patent/US6877554B2/en not_active Expired - Lifetime
- 2001-04-24 US US09/841,497 patent/US6736215B2/en not_active Expired - Fee Related
- 2001-04-24 IL IL15245601A patent/IL152456A0/xx unknown
- 2001-04-24 CA CA2406804A patent/CA2406804C/en not_active Expired - Fee Related
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- 2001-09-24 US US09/841,299 patent/US7036583B2/en not_active Expired - Fee Related
- 2001-10-17 MY MYPI20014833A patent/MY129205A/en unknown
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2002
- 2002-10-16 MA MA26865A patent/MA26148A1/fr unknown
- 2002-10-24 IL IL152455A patent/IL152455A/en not_active IP Right Cessation
- 2002-10-24 IL IL152458A patent/IL152458A/en not_active IP Right Cessation
- 2002-10-24 IL IL152456A patent/IL152456A/en not_active IP Right Cessation
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2003
- 2003-06-12 US US10/460,722 patent/US6923258B2/en not_active Expired - Lifetime
- 2003-10-15 IL IL158427A patent/IL158427A/en not_active IP Right Cessation
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2007
- 2007-05-31 US US11/809,723 patent/US7798221B2/en not_active Expired - Fee Related
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2010
- 2010-07-21 US US12/840,957 patent/US8225866B2/en not_active Expired - Lifetime
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2012
- 2012-07-11 US US13/546,404 patent/US8485252B2/en not_active Expired - Fee Related
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2013
- 2013-07-12 US US13/941,097 patent/US8789586B2/en not_active Expired - Fee Related
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