EP1125037A1 - Verfahren zur sequentiellen anwendung von sagd an benachbarten teilen eines erdölreservoires - Google Patents
Verfahren zur sequentiellen anwendung von sagd an benachbarten teilen eines erdölreservoiresInfo
- Publication number
- EP1125037A1 EP1125037A1 EP99952188A EP99952188A EP1125037A1 EP 1125037 A1 EP1125037 A1 EP 1125037A1 EP 99952188 A EP99952188 A EP 99952188A EP 99952188 A EP99952188 A EP 99952188A EP 1125037 A1 EP1125037 A1 EP 1125037A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- section
- steam
- sagd
- reservoir
- oil
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Withdrawn
Links
- 238000000034 method Methods 0.000 title claims description 15
- 239000003208 petroleum Substances 0.000 title description 2
- 239000003921 oil Substances 0.000 claims abstract description 30
- 238000010796 Steam-assisted gravity drainage Methods 0.000 claims abstract description 27
- 238000010793 Steam injection (oil industry) Methods 0.000 claims abstract description 7
- 239000000295 fuel oil Substances 0.000 claims abstract description 7
- 238000002347 injection Methods 0.000 description 9
- 239000007924 injection Substances 0.000 description 9
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 6
- 239000012530 fluid Substances 0.000 description 5
- 239000007789 gas Substances 0.000 description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 4
- 238000004891 communication Methods 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- 239000003345 natural gas Substances 0.000 description 3
- 238000005553 drilling Methods 0.000 description 2
- 230000003466 anti-cipated effect Effects 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000000977 initiatory effect Effects 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000002093 peripheral effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/2406—Steam assisted gravity drainage [SAGD]
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/2406—Steam assisted gravity drainage [SAGD]
- E21B43/2408—SAGD in combination with other methods
Definitions
- This invention relates to recovering heavy oil from an underground reservoir using a staged process involving, in the first stage, steam assisted gravity drainage, and in the second stage, non-condensible gas injection and reservoir pressurization.
- SAGD Steam assisted gravity drainage
- UTF Underground Test Facility
- AOSTRA Alberta Oil Sands Technology and Research Authority
- the upper well was used to inject steam and the lower well was used to produce a product mixture of heated oil and condensed water.
- the chamber extended along the length of the horizontal portions of the well pair. Oil that had originally filled the chamber sand was heated, to mobilize it, and drained, along with condensed water, down to the production well, through which they were removed.
- the chamber was thus filled with steam and was permeable to liquid flow. Newly injected steam moved through the chamber and supplied heat to its peripheral surface, thereby enlarging the chamber upwardly and outwardly as the oil was mobilized and drained together with the condensed water down to the production well.
- This process is described in greater detail in Canadian patent 1 ,304,287 (Edmunds, Haston and Cordell). The process was shown to be commercially viable and is now being tested by several oil companies in a significant number of pilot projects.
- the Kisman patent teaches injecting a non-condensible gas, such as natural gas, into the more depleted section to raise its pressure and equalize it with the pressure in the relatively undepleted section. By this means, the loss of steam from the one section to the other can be curtailed or minimized.
- the Kisman patent further teaches that pressurizing the more depleted section with natural gas has been characterized by an increase in production rate from that section, if the production well penetrating the section is produced during pressurization.
- Each section is penetrated by one or more wells completed for SAGD operation, preferably one or more pairs of horizontal injection and production wells.
- the process comprises: (a) injecting steam into the first section of the reservoir to practice SAGD and produce contained oil, until the steam/oil ratio rises sufficiently so that further production by SAGD from the section is substantially uneconomic; (b) then reducing or terminating steam injection into the first section and injecting non-condensible gas into the section to maintain it pressurized; (c) continuing to produce oil from the first section while it is pressurized; and (d) concurrently with step (c), injecting steam into the adjacent second section to practice SAGD therein and produce contained oil; (e) while preferably maintaining the first section pressurized to substantially the same pressure as exists in the second section during step (d).
- Steps (b) and (c) constitute a post-steam wind-down of oil production from the first section. Over time, oil production rate will drop off during wind- down and eventually it will again become uneconomic to justify continuing to produce the first section. However it may still be desirable to continue maintaining pressurization in the first section to limit steam loss from the second section.
- the process provides a strategy for sequentially producing adjacent sections across the reservoir. It takes advantage of gas pressurization to prevent steam leakage from a less depleted section undergoing SAGD to a mature, more depleted section. It also maximizes production from each section by subjecting it to sequential SAGD and pressurization production stages.
- DESCRIPTION OF THE PREFERRED EMBODIMENT comprises: (a) directionally drilling one or more pairs of wells from ground surface into a reservoir first section, to provide generally parallel, horizontal, co-extensive, spaced apart, upper and lower well portions extending through the section, and completing the wells for SAGD production; (b) establishing fluid communication between the injection and production wells of each pair, for example by circulating steam through both wells, to heat the span between the wells by heat conduction, and then displacing and draining the oil in the span by injecting steam through the upper injection well and opening the lower production well for production; (c) practising SAGD in the reservoir first section by injecting steam through the injection wells and producing the produced heated oil and condensed water through the production wells while operating said production wells under steam trap control; (d) preparing a second adjoining section of the reservoir for SAGD production by carrying out the provision of wells and establishing fluid communication between the wells of each
- thermocouples • measuring the downhole temperature at the injection and production wells of an operating pair, using thermocouples; • establishing the temperature differential between the two wells and throttling the production well to maintain the differential at a generally constant value (say 7°);
- the invention is characterized by the following advantages:
- a finite steam-producing plant can be applied in sequence to a plurality of adjacent sections of the reservoir, without severe steam loss from a section undergoing SAGD to an adjacent depleted section.
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Chemical And Physical Treatments For Wood And The Like (AREA)
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA2251157 | 1998-10-26 | ||
CA002251157A CA2251157C (en) | 1998-10-26 | 1998-10-26 | Process for sequentially applying sagd to adjacent sections of a petroleum reservoir |
PCT/CA1999/000996 WO2000025002A1 (en) | 1998-10-26 | 1999-10-26 | Process for sequentially applying sagd to adjacent sections of a petroleum reservoir |
Publications (1)
Publication Number | Publication Date |
---|---|
EP1125037A1 true EP1125037A1 (de) | 2001-08-22 |
Family
ID=4162935
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP99952188A Withdrawn EP1125037A1 (de) | 1998-10-26 | 1999-10-26 | Verfahren zur sequentiellen anwendung von sagd an benachbarten teilen eines erdölreservoires |
Country Status (3)
Country | Link |
---|---|
EP (1) | EP1125037A1 (de) |
CA (1) | CA2251157C (de) |
WO (1) | WO2000025002A1 (de) |
Families Citing this family (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CA2351148C (en) | 2001-06-21 | 2008-07-29 | John Nenniger | Method and apparatus for stimulating heavy oil production |
CA2549614C (en) | 2006-06-07 | 2014-11-25 | N-Solv Corporation | Methods and apparatuses for sagd hydrocarbon production |
CA2552482C (en) | 2006-07-19 | 2015-02-24 | N-Solv Corporation | Methods and apparatuses for enhanced in situ hydrocarbon production |
CN101122224B (zh) * | 2006-08-11 | 2010-07-28 | 中国石油天然气股份有限公司 | 一种厚层普通稠油油藏的重力辅助蒸汽驱开采方法 |
US7909094B2 (en) | 2007-07-06 | 2011-03-22 | Halliburton Energy Services, Inc. | Oscillating fluid flow in a wellbore |
CA2631977C (en) | 2008-05-22 | 2009-06-16 | Gokhan Coskuner | In situ thermal process for recovering oil from oil sands |
US9551207B2 (en) | 2011-05-19 | 2017-01-24 | Jason Swist | Pressure assisted oil recovery |
CN102268983B (zh) * | 2011-06-23 | 2015-03-25 | 李剑 | 一种浅油藏提高稠油采收率的混合开采方法 |
CA2762451C (en) | 2011-12-16 | 2019-02-26 | Imperial Oil Resources Limited | Method and system for lifting fluids from a reservoir |
CA2780670C (en) | 2012-06-22 | 2017-10-31 | Imperial Oil Resources Limited | Improving recovery from a subsurface hydrocarbon reservoir |
CN104265253B (zh) * | 2014-08-06 | 2017-01-11 | 中国石油天然气股份有限公司 | 稠油油藏sagd开采方法 |
CA2972203C (en) | 2017-06-29 | 2018-07-17 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
CA2974712C (en) | 2017-07-27 | 2018-09-25 | Imperial Oil Resources Limited | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
CA2978157C (en) | 2017-08-31 | 2018-10-16 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
CA2983541C (en) | 2017-10-24 | 2019-01-22 | Exxonmobil Upstream Research Company | Systems and methods for dynamic liquid level monitoring and control |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB1463444A (de) * | 1975-06-13 | 1977-02-02 | ||
US4166504A (en) * | 1978-08-24 | 1979-09-04 | Texaco Inc. | High vertical conformance steam drive oil recovery method |
US4903768A (en) * | 1989-01-03 | 1990-02-27 | Mobil Oil Corporation | Method for profile control of enhanced oil recovery |
CA2015460C (en) * | 1990-04-26 | 1993-12-14 | Kenneth Edwin Kisman | Process for confining steam injected into a heavy oil reservoir |
CA2055549C (en) * | 1991-11-14 | 2002-07-23 | Tee Sing Ong | Recovering hydrocarbons from tar sand or heavy oil reservoirs |
-
1998
- 1998-10-26 CA CA002251157A patent/CA2251157C/en not_active Expired - Lifetime
-
1999
- 1999-10-26 EP EP99952188A patent/EP1125037A1/de not_active Withdrawn
- 1999-10-26 WO PCT/CA1999/000996 patent/WO2000025002A1/en not_active Application Discontinuation
Non-Patent Citations (1)
Title |
---|
See references of WO0025002A1 * |
Also Published As
Publication number | Publication date |
---|---|
CA2251157C (en) | 2003-05-27 |
WO2000025002A1 (en) | 2000-05-04 |
CA2251157A1 (en) | 2000-04-26 |
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Legal Events
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PUAI | Public reference made under article 153(3) epc to a published international application that has entered the european phase |
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Effective date: 20010404 |
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STAA | Information on the status of an ep patent application or granted ep patent |
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Effective date: 20030304 |