CA2652159A1 - Recovery of hydrocarbons using horizontal wells - Google Patents
Recovery of hydrocarbons using horizontal wells Download PDFInfo
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- CA2652159A1 CA2652159A1 CA002652159A CA2652159A CA2652159A1 CA 2652159 A1 CA2652159 A1 CA 2652159A1 CA 002652159 A CA002652159 A CA 002652159A CA 2652159 A CA2652159 A CA 2652159A CA 2652159 A1 CA2652159 A1 CA 2652159A1
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- Prior art keywords
- wellbore
- steam
- wellbores
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- Abandoned
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- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 10
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 10
- 238000011084 recovery Methods 0.000 title claims abstract description 7
- 238000000034 method Methods 0.000 claims abstract description 33
- 238000005553 drilling Methods 0.000 claims abstract description 15
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical group O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 5
- 230000001186 cumulative effect Effects 0.000 claims description 5
- 239000000295 fuel oil Substances 0.000 claims description 4
- 239000003921 oil Substances 0.000 description 20
- 230000014509 gene expression Effects 0.000 description 19
- 206010017076 Fracture Diseases 0.000 description 17
- 238000004519 manufacturing process Methods 0.000 description 14
- 238000010025 steaming Methods 0.000 description 11
- 125000004122 cyclic group Chemical group 0.000 description 8
- 208000010392 Bone Fractures Diseases 0.000 description 6
- 230000005484 gravity Effects 0.000 description 6
- 238000010793 Steam injection (oil industry) Methods 0.000 description 5
- 230000007246 mechanism Effects 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 4
- 238000005755 formation reaction Methods 0.000 description 4
- 230000008569 process Effects 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 230000005012 migration Effects 0.000 description 3
- 238000013508 migration Methods 0.000 description 3
- 239000011435 rock Substances 0.000 description 3
- 230000010339 dilation Effects 0.000 description 2
- 230000004044 response Effects 0.000 description 2
- 241000117281 Aora Species 0.000 description 1
- 241000282817 Bovidae Species 0.000 description 1
- 208000002565 Open Fractures Diseases 0.000 description 1
- 239000008186 active pharmaceutical agent Substances 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 235000013405 beer Nutrition 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000007598 dipping method Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 235000015250 liver sausages Nutrition 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000037361 pathway Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 230000002459 sustained effect Effects 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 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
-
- 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
- E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
- E21B43/305—Specific pattern of wells, e.g. optimising the spacing of wells comprising at least one inclined or horizontal well
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- 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)
- Earth Drilling (AREA)
Abstract
A method of drilling a wellbore useful for the recovery of hydrocarbons from a subsurface reservoir, penetrated by one or more wellbores previously injected with steam, comprises drilling a wellbore having a substantially horizontal productive portion lying within the subsurface reservoir.
Description
RECOVERY OF HYDROCARBONS USING HORIZONTAL WELLS
GROSS REFERENCE TO P;F! ATED ,A,:PPLiCRT!ONS
The present application claims priority under 35 U.S.C. 119 to U.S.
Provisional Patent Application No. 601801,01(3 filed on May 16, 2006, the entire contentof wtiich is hereby incorporated by referetice.
QACKGROUND
Field of Art Provided is a method that relates to the recovery of hydrocarbons in subsrErface formations, particularly the t-ecovery of heavy oil from reservoirs in whicti steam fracturing operations have beer) conducted.
Background of the Related Art Unconventional, heavy 611 reserves, ~~ich as, for example, Miocene diatomite (Opal A), can be recovered through iPstearh tracturir$g>:: Steam fracturing takes place through a cyclic process with characteristics that include injection pressures of approximately 1000 psi ara-dtempet-atLires of "l. 500-55+0 F. Commonly assigned U,S. Pate{ifi Nns. 5,085,27'n and 5,305,829 disclose process(es) for cyclic stUaming that are applicable to dietoii-+Ãte #orriiatioras. Such processing generally includes:
*: SÃeaming. Injection trakes ~~aee for 2-3 days (aplaraximatcly 1000-25: 1500 Barrels of Stearn Per Day or BSPD) until a target volume of steam (e.g., 3000-5000 barrels of steam) is achieved. Th.e steam is injected at approximately 1000 psi, wliich typically serves to exceed the fracture gradient of the sdbsurfac:e rock, fracture the low-permeability resen+lolr (5 rnillidarcy or rnD); at7cf ci-eate secondary fracture permeability.
* Soak Period. After stearnÃng the well, the well is shut in and "soaked" for approximately 2 days. ~ he 4itgh temperature providea necessary viscosity reductiork for the 13 ,API oil and allows the oil to flow more easily. In -~P
addition, a process known as inibibition takes place, in which condensed steam vapor is preferentially imbibed by the (hydrolahi4ic) diatomite rock and oil is displaced into fractures and the well bore.
~Producti:dn. After "saaking' the we]f, the weÃl is produced for approximately 20 or more days. The production causes a pressure drop, which induces "tlashir~g" of hotwater to steam, which provides lift energy for the fluid column. As a result; the wells flow and do not have to be artificially lifted, as long as the wells are subsequently stearrted. Typically, a flowing wellhead cQnf`iguratioh is used for cyclic steaming at a heavy oil field. After a well dies, the well is prepared for the next steam job.
SUMMARY
frt an embodiment, provided is a method of drilling a wellbore useful for the rea;Overy of hydrocarbons frorti a subsurface reservoir, the method comprising drilling a wellbore having a suhstantialiy horizontal pmductive portion lying within the subsurface reservoir; The subsurface reservoir is penetrated by oiie or rriorc- wellhores previously injected with steam.
In an embodiment, provided is a method of driliin~ a wellbore useful for the recovery of hydrocarbons from a subsurface reservoir, the method comprising drilling a wellborO having a substantially horizontal productive portion lying within the subsurface reservoir; drilling one or more substantially verticel wellbores; and perforating the one or more substantially vertical vuellbores according to a depth of the substantially horizontal productive portion of the wellbore:
BRIEF DESCRIPTION of the FIGURES OF THE DRAWINGS
The appended drawings illustrate typic~al embodiments and are not to be considered limiting in scope.
FIGURE 1 shows a cross-section of the first horizontal well of the Example. The productive interval (slotted liner) for the first horizontal well of
GROSS REFERENCE TO P;F! ATED ,A,:PPLiCRT!ONS
The present application claims priority under 35 U.S.C. 119 to U.S.
Provisional Patent Application No. 601801,01(3 filed on May 16, 2006, the entire contentof wtiich is hereby incorporated by referetice.
QACKGROUND
Field of Art Provided is a method that relates to the recovery of hydrocarbons in subsrErface formations, particularly the t-ecovery of heavy oil from reservoirs in whicti steam fracturing operations have beer) conducted.
Background of the Related Art Unconventional, heavy 611 reserves, ~~ich as, for example, Miocene diatomite (Opal A), can be recovered through iPstearh tracturir$g>:: Steam fracturing takes place through a cyclic process with characteristics that include injection pressures of approximately 1000 psi ara-dtempet-atLires of "l. 500-55+0 F. Commonly assigned U,S. Pate{ifi Nns. 5,085,27'n and 5,305,829 disclose process(es) for cyclic stUaming that are applicable to dietoii-+Ãte #orriiatioras. Such processing generally includes:
*: SÃeaming. Injection trakes ~~aee for 2-3 days (aplaraximatcly 1000-25: 1500 Barrels of Stearn Per Day or BSPD) until a target volume of steam (e.g., 3000-5000 barrels of steam) is achieved. Th.e steam is injected at approximately 1000 psi, wliich typically serves to exceed the fracture gradient of the sdbsurfac:e rock, fracture the low-permeability resen+lolr (5 rnillidarcy or rnD); at7cf ci-eate secondary fracture permeability.
* Soak Period. After stearnÃng the well, the well is shut in and "soaked" for approximately 2 days. ~ he 4itgh temperature providea necessary viscosity reductiork for the 13 ,API oil and allows the oil to flow more easily. In -~P
addition, a process known as inibibition takes place, in which condensed steam vapor is preferentially imbibed by the (hydrolahi4ic) diatomite rock and oil is displaced into fractures and the well bore.
~Producti:dn. After "saaking' the we]f, the weÃl is produced for approximately 20 or more days. The production causes a pressure drop, which induces "tlashir~g" of hotwater to steam, which provides lift energy for the fluid column. As a result; the wells flow and do not have to be artificially lifted, as long as the wells are subsequently stearrted. Typically, a flowing wellhead cQnf`iguratioh is used for cyclic steaming at a heavy oil field. After a well dies, the well is prepared for the next steam job.
SUMMARY
frt an embodiment, provided is a method of drilling a wellbore useful for the rea;Overy of hydrocarbons frorti a subsurface reservoir, the method comprising drilling a wellbore having a suhstantialiy horizontal pmductive portion lying within the subsurface reservoir; The subsurface reservoir is penetrated by oiie or rriorc- wellhores previously injected with steam.
In an embodiment, provided is a method of driliin~ a wellbore useful for the recovery of hydrocarbons from a subsurface reservoir, the method comprising drilling a wellborO having a substantially horizontal productive portion lying within the subsurface reservoir; drilling one or more substantially verticel wellbores; and perforating the one or more substantially vertical vuellbores according to a depth of the substantially horizontal productive portion of the wellbore:
BRIEF DESCRIPTION of the FIGURES OF THE DRAWINGS
The appended drawings illustrate typic~al embodiments and are not to be considered limiting in scope.
FIGURE 1 shows a cross-section of the first horizontal well of the Example. The productive interval (slotted liner) for the first horizontal well of
-2-the Example intersects intervals above top perforations of vertical wells. The intervals above the top perforations of the vertical wells are interpreted to be heated and highly fractured, due to steaming of the vertical wells (prior to abandanriien#).
FlGURIE 2 shows a cross-section through an oil saturation model depicting the lateral section of the first horizontal well of the Example. The view is looking to the north-northwest direction atthe steep dips of the formation, and the schematic indicates that gravity drairaage could be a significant component of the producing mechanism for the first horizontal well of the Example.
DETAILED DESCRIPTION
While Keavy oil reserves can be recovered through known "staam fracturing" processes, it has been discovered, as indicated by data acquired through the use of surface tiitrnatersõ that, during some steam cycles, fugitive steam migration carsaccur in the overburden (i.e., above the reservoir). The ft,gitÃve steam migratÃon is believed to be caused by shallow casing damage or out-of-zone fracturing and result in higher than normal pressures in the bvarburden. The higher than normal pressures are believed to cause surface expressions, di-ilÃirZg issues, workover difficulties and surface uplift. As used herein, "surface expressions" refer to high-pressure voli:ir7ies of steam and oil that breach the surface and rasuit in recordable spills. Recordable spills are not only costly from ail i-Ã'=.S (health-environmental-safety) standpoint, but can also lead to significant lost praciuctiWrevenue if steaming is curtailed as a result. In particular-0surface expressiorrs can lead to the abandonment of damaged (or assumed damaged) wellbores.
A surface expression can lead to a moratorium on drillirsglsteamirsg new replacement or infill wells in the area of the surface expression, as well as a morator um on operating remaining wells around the surface expression by conventional cyclic steaniing means, for fear of agitating the surface expression. It was surprisingly discovered that such remaining wells, when
FlGURIE 2 shows a cross-section through an oil saturation model depicting the lateral section of the first horizontal well of the Example. The view is looking to the north-northwest direction atthe steep dips of the formation, and the schematic indicates that gravity drairaage could be a significant component of the producing mechanism for the first horizontal well of the Example.
DETAILED DESCRIPTION
While Keavy oil reserves can be recovered through known "staam fracturing" processes, it has been discovered, as indicated by data acquired through the use of surface tiitrnatersõ that, during some steam cycles, fugitive steam migration carsaccur in the overburden (i.e., above the reservoir). The ft,gitÃve steam migratÃon is believed to be caused by shallow casing damage or out-of-zone fracturing and result in higher than normal pressures in the bvarburden. The higher than normal pressures are believed to cause surface expressions, di-ilÃirZg issues, workover difficulties and surface uplift. As used herein, "surface expressions" refer to high-pressure voli:ir7ies of steam and oil that breach the surface and rasuit in recordable spills. Recordable spills are not only costly from ail i-Ã'=.S (health-environmental-safety) standpoint, but can also lead to significant lost praciuctiWrevenue if steaming is curtailed as a result. In particular-0surface expressiorrs can lead to the abandonment of damaged (or assumed damaged) wellbores.
A surface expression can lead to a moratorium on drillirsglsteamirsg new replacement or infill wells in the area of the surface expression, as well as a morator um on operating remaining wells around the surface expression by conventional cyclic steaniing means, for fear of agitating the surface expression. It was surprisingly discovered that such remaining wells, when
-3-converted to artificia1 lift (rod-pump) without active steam injection, in order to help reduce surface dilation and continue to recover reserves in close proximity to the surface expression, produced at rates exceeding expectations.
Thus, high oil production from the post-steam, artificial lift (rod-pump) wellsF without direct cyclic steam injection, led to the eXp[ora#aora of whether the performance of rod-pump wells could be dUpÃÃcatec' with a horizontal well. It was discovered that a horizontal well could intersect the cyclic-steam induced fractures of abandoned vertical wells and still be productive without steam irij.ection, Without wishing to be bound by any, theory, it is believed that the production mechanisms for artificial lift wells in the teservoir are three-foÃd, First, gravity drainage likely assists in areas of steeply-dipping beds and thus oil can migrate within a single pattern. Second, established, open-fractures (both steam-induced and natural) play a major role in providing migration pathways for the oil in the low-permeability matrix rock. Third, the remaining heat from prior cyclic steaming, along with steaming on the periphery of the area, both play arn important role in the heating and viscosity reduction of the The area near a surface expression can be characterized as one that has both steam-induced fractures as lueÃl as existing natural fractures. The high frequency of natural fractures can be documented near surface expressions thraugh a detailed FMI/EMI (eÃectrornagryetic interference) study.
Without wistiirig to be bound by any theory, it is believed that the natural fractures, along with steam-induced fractures, likely create a network that can be supplied with steam and can become "pressured", as well as further heated, which allows for the production of oil through an artificial lift mechan.ism and does not necessarily require active injection in the producing slveÃfbcre.
While not clear how far steam and pressure can propagate through existing fractures in the area of a field near a surface expression, rod-purnp response to aggressive steaming suggests that the methods disclosed herein are a viable mechanism for corstinual resurgence in production.
As used herein, the phrase "substantiai3y vertical" refers toan orientation of approximately 30 or less frorn vertical, while the phrase "substantially
Thus, high oil production from the post-steam, artificial lift (rod-pump) wellsF without direct cyclic steam injection, led to the eXp[ora#aora of whether the performance of rod-pump wells could be dUpÃÃcatec' with a horizontal well. It was discovered that a horizontal well could intersect the cyclic-steam induced fractures of abandoned vertical wells and still be productive without steam irij.ection, Without wishing to be bound by any, theory, it is believed that the production mechanisms for artificial lift wells in the teservoir are three-foÃd, First, gravity drainage likely assists in areas of steeply-dipping beds and thus oil can migrate within a single pattern. Second, established, open-fractures (both steam-induced and natural) play a major role in providing migration pathways for the oil in the low-permeability matrix rock. Third, the remaining heat from prior cyclic steaming, along with steaming on the periphery of the area, both play arn important role in the heating and viscosity reduction of the The area near a surface expression can be characterized as one that has both steam-induced fractures as lueÃl as existing natural fractures. The high frequency of natural fractures can be documented near surface expressions thraugh a detailed FMI/EMI (eÃectrornagryetic interference) study.
Without wistiirig to be bound by any theory, it is believed that the natural fractures, along with steam-induced fractures, likely create a network that can be supplied with steam and can become "pressured", as well as further heated, which allows for the production of oil through an artificial lift mechan.ism and does not necessarily require active injection in the producing slveÃfbcre.
While not clear how far steam and pressure can propagate through existing fractures in the area of a field near a surface expression, rod-purnp response to aggressive steaming suggests that the methods disclosed herein are a viable mechanism for corstinual resurgence in production.
As used herein, the phrase "substantiai3y vertical" refers toan orientation of approximately 30 or less frorn vertical, while the phrase "substantially
-4-hor[zontal" refers to an orientation of approxfmate-ly 30" or less from the ht]rizC}rata7.
F~~t-n a strictly subsurface stand,poin.t, there are a few basic criteria to be followed when planning a welipath of ahorizontal welt. The criteria are used to create a"best-fit" line for a lateral section of the well. Exemplary criteria include:
1) The path should be within approximately 50 feet of targeted abandoned wel I s.
2) The path should pass by the abandoned wells at an elevation no greater than approximately 160 feet above(in TVDSa) top perforations of the abandoned wells.
3) The path should pass by the abandoned wells at a TVDSS elevation that would be no lower than bottom perforations for the abandoned wrelis:
4) The interpreted fracture networks from abandoned wells was targeted with greater than 150,000 barrels (CWE) of cumulative steam injection.
As disclosed herein, horizontal rod-punip We1ls are viable options to cyclic steaming in thermally mature areas, by taking advantage of a combination of steam-iraduGed and natural fractures and gravity drainage of hot, mobile oil. Exemplary uses ioclode:'lI ) Drilling horizontal Welis to supplement existing vertical wells or replace vertical abandoned wells, when the vertical wells have previously been injected with greater than 50,000 cumulative barrels of steam (Cold {Jllatei-Equivalenà or CWE) and the lateral (ProduetiQn) section of the horizontal well is generally between the depths (total rertiCaldeptb subsea or TVDSS) of top and bottom perforations of offset vertical wells (when passing by the vertical vvells), In one embodiment, the depth range is within approxirriately 200 feet TVDSS
(height) from the top perforation of the vertical wells or approximately 50 feet TVDSS (depth) below bottom perforation ottbe ve.rtica# wefls.
2) Drilling horizontal wells in a thermal diatomitc field such that a productive portion of the horizontal well lies within approximately 100 feet from all existing or abandoned vuelis that have previously been injected with greater
F~~t-n a strictly subsurface stand,poin.t, there are a few basic criteria to be followed when planning a welipath of ahorizontal welt. The criteria are used to create a"best-fit" line for a lateral section of the well. Exemplary criteria include:
1) The path should be within approximately 50 feet of targeted abandoned wel I s.
2) The path should pass by the abandoned wells at an elevation no greater than approximately 160 feet above(in TVDSa) top perforations of the abandoned wells.
3) The path should pass by the abandoned wells at a TVDSS elevation that would be no lower than bottom perforations for the abandoned wrelis:
4) The interpreted fracture networks from abandoned wells was targeted with greater than 150,000 barrels (CWE) of cumulative steam injection.
As disclosed herein, horizontal rod-punip We1ls are viable options to cyclic steaming in thermally mature areas, by taking advantage of a combination of steam-iraduGed and natural fractures and gravity drainage of hot, mobile oil. Exemplary uses ioclode:'lI ) Drilling horizontal Welis to supplement existing vertical wells or replace vertical abandoned wells, when the vertical wells have previously been injected with greater than 50,000 cumulative barrels of steam (Cold {Jllatei-Equivalenà or CWE) and the lateral (ProduetiQn) section of the horizontal well is generally between the depths (total rertiCaldeptb subsea or TVDSS) of top and bottom perforations of offset vertical wells (when passing by the vertical vvells), In one embodiment, the depth range is within approxirriately 200 feet TVDSS
(height) from the top perforation of the vertical wells or approximately 50 feet TVDSS (depth) below bottom perforation ottbe ve.rtica# wefls.
2) Drilling horizontal wells in a thermal diatomitc field such that a productive portion of the horizontal well lies within approximately 100 feet from all existing or abandoned vuelis that have previously been injected with greater
-5,-than 50,000 barrels of steam (CWE), in accordance with the aforementioned parameters for depth relative to perforations of offset vertical wells. In an embodiment, the productive portion of the horizontal ti^aell can be defined as any well completion (perforated or slvtted liner) that iq- at an angle of 90', or hiq'ner.
and is used for inflow of oil and water.
3) Drilling horizontal wells in thermal diatomite, followed by driiling and completing vertical wells according to the aforementioned parameters for depths of perforations, relative. to the productive portion of the horizontal well:
Essentially, the horizontal well disclosed herein employs a "fract-urelheat salvaqe" approach for production in heavy oil fields such as, for example, thermal diatomite settings.
Example The following illustrative example is intended to be non-limiting.
is A surface expression led to a moratorium on dri4iing/steamin:g new replacement or infill wells, within a 500 feet radius of the surface expression.
The great number (r',e., twenty two) of abandoned wells and the restricted steaming policy led to significant loss of production (on the order of approximately 1000 Barrels Per Day or BPD) irR the area of the surface expressioh.;
Despite the abandonment of several active wells around the surface expression, there were several -,vel1s that rerrgained. The several remaining wells were not bperated by conventional cyclic steaming means, for fear of agitating the surface expression. Thus, one well was converted to art:ificial lift (rod-pump) in order to increase Antelope Withdravval, help reduce surface dilation, and continue to recover reserves in close proximity to the surface expression. SurprisiÃigly; without active steam injection, the well produced at rates exceeding expectations (on the order of hundreds of BPD), until casing damage necessitated the abandonment of the cc?nveE-fPd well. Shortly after the conversion to rod-PUMP, four other producing wells were also equipped with rod-pumps. The four additional converted wells also responded positively.
and is used for inflow of oil and water.
3) Drilling horizontal wells in thermal diatomite, followed by driiling and completing vertical wells according to the aforementioned parameters for depths of perforations, relative. to the productive portion of the horizontal well:
Essentially, the horizontal well disclosed herein employs a "fract-urelheat salvaqe" approach for production in heavy oil fields such as, for example, thermal diatomite settings.
Example The following illustrative example is intended to be non-limiting.
is A surface expression led to a moratorium on dri4iing/steamin:g new replacement or infill wells, within a 500 feet radius of the surface expression.
The great number (r',e., twenty two) of abandoned wells and the restricted steaming policy led to significant loss of production (on the order of approximately 1000 Barrels Per Day or BPD) irR the area of the surface expressioh.;
Despite the abandonment of several active wells around the surface expression, there were several -,vel1s that rerrgained. The several remaining wells were not bperated by conventional cyclic steaming means, for fear of agitating the surface expression. Thus, one well was converted to art:ificial lift (rod-pump) in order to increase Antelope Withdravval, help reduce surface dilation, and continue to recover reserves in close proximity to the surface expression. SurprisiÃigly; without active steam injection, the well produced at rates exceeding expectations (on the order of hundreds of BPD), until casing damage necessitated the abandonment of the cc?nveE-fPd well. Shortly after the conversion to rod-PUMP, four other producing wells were also equipped with rod-pumps. The four additional converted wells also responded positively.
-6-When planning the first horizontal well, the exemplary well planning criteria as disclosed herein were focused on to ensure that the weiipath would be close enough to the abandoned wells, so as to capitalize on steam-induced fracturing and heatirig (see FfGURE'(i). Specifically, the productive portion, or productive interval (slotted liner), for the first horizontal well intersected intervals above the top laerforations of the vertical we(ls. The intersected intervals above the top perforations Atere ititerpreted to beheated and highly fractured, due to steaming of the vertical wells (prior to abandonment).
The path cfthe first horizontal well targeted four previously abandoned wells in the area of the surface expression. The first horizontal well took a littÃe over a week to drill and complete. The well was put on production with an initial production (IP) exceeding 1400 Barrels of Oil Per Day (BOPO). The first horizontal well had sustained production exceeding the average well production in the field by a factor of ten..
Prior to drilling the first horizontal well, the hypothesized mechanism for production was that the horizontal well would take advantage of the years of historic steam injection in the area by intersecting both steam-induced and.
natural fractures and also benefit frorn gravity drainage in the reservoir and wellhore (heel-to-toe elevation change rises 12 ). Theperfotmance of the first horizontal well substantiates the hypotheses and suggests contribution frram the majority of lateral section.
In addition to the first horizontal well, two additional horizontal well opportunities in the field were identified and capitalized on. The two additional horizontal wells were planned and drilled parallel to thefirst horizontal well, with the path of the second and third additional horizontal wells targo-ting six and five previously abandoned wells in the area of the surface expression, respectively.
FIGURE 2 is a cr~ss-sectiort through an oil saturation model for the oil field in which the surface expressian occurred, showing the steep dips of the formation. Without wishing to be bound by any theory, it is believed that steep dips of the formation of tFie oil field in which the surface expression occurred, along with natural and stearn-inciuced fractures, allow for the likelihood that gravity drainage could have been a significant component of the praductic)n
The path cfthe first horizontal well targeted four previously abandoned wells in the area of the surface expression. The first horizontal well took a littÃe over a week to drill and complete. The well was put on production with an initial production (IP) exceeding 1400 Barrels of Oil Per Day (BOPO). The first horizontal well had sustained production exceeding the average well production in the field by a factor of ten..
Prior to drilling the first horizontal well, the hypothesized mechanism for production was that the horizontal well would take advantage of the years of historic steam injection in the area by intersecting both steam-induced and.
natural fractures and also benefit frorn gravity drainage in the reservoir and wellhore (heel-to-toe elevation change rises 12 ). Theperfotmance of the first horizontal well substantiates the hypotheses and suggests contribution frram the majority of lateral section.
In addition to the first horizontal well, two additional horizontal well opportunities in the field were identified and capitalized on. The two additional horizontal wells were planned and drilled parallel to thefirst horizontal well, with the path of the second and third additional horizontal wells targo-ting six and five previously abandoned wells in the area of the surface expression, respectively.
FIGURE 2 is a cr~ss-sectiort through an oil saturation model for the oil field in which the surface expressian occurred, showing the steep dips of the formation. Without wishing to be bound by any theory, it is believed that steep dips of the formation of tFie oil field in which the surface expression occurred, along with natural and stearn-inciuced fractures, allow for the likelihood that gravity drainage could have been a significant component of the praductic)n
-7-mechanism for some horizontal wells at the oil field. Bedding dips can exceed 45 in the part of the field where the three horizontal wells were drilled and hot, mobile oil can drain down the steep beds. If a gravity drainage mechanism was taking place,then lateral portions of the three horizonÃal wells were in favorable position to capture the hot, mobile oll:
Previous near-weIlbore .+alumetric calculations indicated that a considerable portion of the oil in the first horizontal well path was drained within 25 feet of the abandoned wellbores. However, the same study also concluded similar results for the aforementioned vertical rod-pump producers: The actual performance of the first horizontal well (discussed below), along with the rod-pump production response to offset steaming, suggests that oil production can be contributed from further than 25 feet away (from bottomhole location), which suggests that a fracture network exists in the mature area of the surface expression and the fracture network likely allows for the migration of steam and Oif.
Many modifications of the exemplary embodiments disclosed herein will readily occur to ttsose of skill in the art. The present disclosure is intended for purposes of illustration only ari.d should not be construed in a limiting sense.
Accordingly, the present disclosure is to be construed as including all structure and methods that fall within the scope of the appended claims. The term "camprisirrg , vvithin the claims is intended to mean "including at ieast' such that the recited listir-g of elements in a claitan are an. open set or group.
Similarly, the terms "containing,," having,,, and including" are all intended to mean an open set or grorip of elements. "A,, an ` and other singular terms are intended to include the plural forms thereof unless specifically excluded.
Previous near-weIlbore .+alumetric calculations indicated that a considerable portion of the oil in the first horizontal well path was drained within 25 feet of the abandoned wellbores. However, the same study also concluded similar results for the aforementioned vertical rod-pump producers: The actual performance of the first horizontal well (discussed below), along with the rod-pump production response to offset steaming, suggests that oil production can be contributed from further than 25 feet away (from bottomhole location), which suggests that a fracture network exists in the mature area of the surface expression and the fracture network likely allows for the migration of steam and Oif.
Many modifications of the exemplary embodiments disclosed herein will readily occur to ttsose of skill in the art. The present disclosure is intended for purposes of illustration only ari.d should not be construed in a limiting sense.
Accordingly, the present disclosure is to be construed as including all structure and methods that fall within the scope of the appended claims. The term "camprisirrg , vvithin the claims is intended to mean "including at ieast' such that the recited listir-g of elements in a claitan are an. open set or group.
Similarly, the terms "containing,," having,,, and including" are all intended to mean an open set or grorip of elements. "A,, an ` and other singular terms are intended to include the plural forms thereof unless specifically excluded.
-8-
Claims (20)
1 . A method of drilling a wellbore useful for the recovery of hydrocarbons from a subsurface reservoir, the method comprising:
drilling a wellbore comprising a substantially horizontal productive portion lying within the subsurface reservoir;
wherein the subsurface reservoir is penetrated by one or more wellbores previously injected with steam.
drilling a wellbore comprising a substantially horizontal productive portion lying within the subsurface reservoir;
wherein the subsurface reservoir is penetrated by one or more wellbores previously injected with steam.
2. The method of claim 1, further comprising producing hydrocarbons from the wellbore.
3. The method of claim 1, wherein the subsurface reservoir has achieved a threshold thermal maturity from the steam previously injected therein.
4. The method of claim 1, wherein the subsurface reservoir is penetrated by one or more wellbores previously injected with at least 50,000 cumulative barrels of steam.
5. The method of claim 1, wherein the subsurface reservoir is penetrated by one or more wellbores previously injected with at least 150,000 cumulative barrels of steam.
6. The method of claim 1, wherein the subsurface reservoir is penetrated by one or more substantially vertical wellbores previously injected with steam.
7. The method of claim 6, further comprising positioning the substantially horizontal productive portion of the wellbore within a lateral range of approximately 100 feet of one or more of the substantially vertical wellbores.
8. The method of claim 6, further comprising positioning the substantially horizontal productive portion of the wellbore at a depth defined by top-most and bottom-most perforations of one or more of the substantially vertical wellbores.
9. The method of claim 6, further comprising positioning the substantially horizontal productive portion of the wellbore within a depth range defined by an upper depth limit of approximately 200 feet TVDSS above a top-most perforation of one or more of the substantially vertical wellbores and a lower depth limit of approximately 50 feet TVDSS beneath a bottom-most perforation of one or more of the substantially vertical wellbores.
10. The method of claim 6, further comprising positioning the substantially horizontal productive portion of the wellbore a depth range defined by an upper depth limit of approximately 160 feet TVDSS above a top-most perforation of one or more of the substantially vertical wellbores and a lower depth limit no lower than a bottom-most perforation of one or more of the substantially vertical wellbores.
11. The method of claim 1, wherein the subsurface reservoir is a heavy oil reservoir.
12. The method of claim 11, wherein the subsurface reservoir is a diatomite reservoir.
13. The method of claim 1, further comprising planning a path of the substantially horizontal productive portion of the wellbore to be within a lateral range of approximately 100 feet of one or more of the wellbores previously injected with steam.
14. The method of claim 1, further comprising planning a path of the substantially horizontal productive portion of the wellbore to be within a lateral range of approximately 50 feet of one or more of the wellbores previously injected with steam.
15. A drilled wellbore comprising:
a substantially horizontal productive portion lying within a subsurface reservoir, wherein the subsurface reservoir is penetrated by one or more substantially vertical wellbores, the substantially horizontal productive portion located:
within a depth range defined by an upper depth limit of approximately 200 feet TVDSS above a top-most perforation of one or more of the substantially vertical wellbores and a lower depth limit of approximately 50 feet TVDSS beneath a bottom-most perforation of one or more of the substantially vertical wellbores; and within a lateral range of approximately 100 feet of one or more of the wellbores previously injected with steam.
a substantially horizontal productive portion lying within a subsurface reservoir, wherein the subsurface reservoir is penetrated by one or more substantially vertical wellbores, the substantially horizontal productive portion located:
within a depth range defined by an upper depth limit of approximately 200 feet TVDSS above a top-most perforation of one or more of the substantially vertical wellbores and a lower depth limit of approximately 50 feet TVDSS beneath a bottom-most perforation of one or more of the substantially vertical wellbores; and within a lateral range of approximately 100 feet of one or more of the wellbores previously injected with steam.
16. A method of drilling a wellbore useful for the recovery of hydrocarbons from a subsurface reservoir, the method comprising:
drilling a wellbore comprising a substantially horizontal productive portion lying within the subsurface reservoir;
drilling one or more substantially vertical wellbores; and perforating the one or more substantially vertical wellbores according to a depth of the substantially horizontal productive portion of the wellbore.
drilling a wellbore comprising a substantially horizontal productive portion lying within the subsurface reservoir;
drilling one or more substantially vertical wellbores; and perforating the one or more substantially vertical wellbores according to a depth of the substantially horizontal productive portion of the wellbore.
17. The method of claim 16, further comprising producing hydrocarbons from the wellbore.
18. The method of claim 16, wherein a top-most perforation of the one or more substantially vertical wellbores occurs not lower than approximately 200 feet TVDSS beneath the substantially horizontal productive portion of the wellbore and a bottom-most perforation of the one or more substantially vertical wellbores occurs not more than approximately 50 feet TVDSS above the substantially horizontal productive portion of the wellbore.
19. The method of claim 16, wherein the subsurface reservoir is penetrated by one or more wellbores previously injected with at least 50,000 cumulative barrels of steam.
20. The method of claim 16, further comprising planning a path of the substantially horizontal productive portion of the wellbore to be within a lateral range of approximately 100 feet of one or more of the wellbores previously injected with steam.
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| US80101606P | 2006-05-16 | 2006-05-16 | |
| US60/801,016 | 2006-05-16 | ||
| PCT/US2007/069027 WO2007137061A2 (en) | 2006-05-16 | 2007-05-16 | Recovery of hydrocarbons using horizontal wells |
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| CA2652159A1 true CA2652159A1 (en) | 2007-11-29 |
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| CN (1) | CN101484662B (en) |
| BR (1) | BRPI0711475A2 (en) |
| CA (1) | CA2652159A1 (en) |
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| US7784543B2 (en) | 2007-10-19 | 2010-08-31 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
| US7775277B2 (en) | 2007-10-19 | 2010-08-17 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
| US7775271B2 (en) * | 2007-10-19 | 2010-08-17 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
| US7793714B2 (en) * | 2007-10-19 | 2010-09-14 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
| US7789139B2 (en) * | 2007-10-19 | 2010-09-07 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
| US7913755B2 (en) | 2007-10-19 | 2011-03-29 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
| US20090101336A1 (en) * | 2007-10-19 | 2009-04-23 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
| US8171999B2 (en) | 2008-05-13 | 2012-05-08 | Baker Huges Incorporated | Downhole flow control device and method |
| US8113292B2 (en) | 2008-05-13 | 2012-02-14 | Baker Hughes Incorporated | Strokable liner hanger and method |
| US7789152B2 (en) | 2008-05-13 | 2010-09-07 | Baker Hughes Incorporated | Plug protection system and method |
| US8555958B2 (en) | 2008-05-13 | 2013-10-15 | Baker Hughes Incorporated | Pipeless steam assisted gravity drainage system and method |
| US8132624B2 (en) | 2009-06-02 | 2012-03-13 | Baker Hughes Incorporated | Permeability flow balancing within integral screen joints and method |
| US8056627B2 (en) | 2009-06-02 | 2011-11-15 | Baker Hughes Incorporated | Permeability flow balancing within integral screen joints and method |
| US8151881B2 (en) | 2009-06-02 | 2012-04-10 | Baker Hughes Incorporated | Permeability flow balancing within integral screen joints |
| WO2011081665A1 (en) * | 2009-12-28 | 2011-07-07 | Enis Ben M | Sequestering co2 and releasing natural gas from coal and gas shale formations |
| WO2012092404A1 (en) | 2010-12-28 | 2012-07-05 | Enis Ben M | Method and apparatus for using pressure cycling and cold liquid co2 for releasing natural gas from coal and shale formations |
| CN102213089A (en) * | 2011-06-02 | 2011-10-12 | 中国石油天然气股份有限公司 | Method and system for extracting oil from shallow heavy oil reservoir |
| US20130020080A1 (en) * | 2011-07-20 | 2013-01-24 | Stewart Albert E | Method for in situ extraction of hydrocarbon materials |
| AU2013378802B2 (en) * | 2013-02-22 | 2016-06-30 | Exxonmobil Upstream Research Company | Subwater heat exchanger |
| CN104863559A (en) * | 2014-02-26 | 2015-08-26 | 中国石油化工股份有限公司 | Method for increasing single well productivity of ultra-deep-layer low-permeability heavy oil reservoir |
| DE102015121042A1 (en) * | 2015-12-03 | 2017-06-08 | Benjamin Klock | Method and device for the in-situ remediation of contaminated soils |
| US20230237223A1 (en) * | 2022-01-26 | 2023-07-27 | Chevron U.S.A. Inc. | Systems and methods for estimating well interference on a target well from other potential wells in a subsurface volume of interest |
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| US5085276A (en) * | 1990-08-29 | 1992-02-04 | Chevron Research And Technology Company | Production of oil from low permeability formations by sequential steam fracturing |
| US5085273A (en) * | 1990-10-05 | 1992-02-04 | Davis-Lynch, Inc. | Casing lined oil or gas well |
| US5305829A (en) * | 1992-09-25 | 1994-04-26 | Chevron Research And Technology Company | Oil production from diatomite formations by fracture steamdrive |
| US6050335A (en) * | 1997-10-31 | 2000-04-18 | Shell Oil Company | In-situ production of bitumen |
| CN1081288C (en) * | 1999-03-25 | 2002-03-20 | 金军 | Steam chemical incoming-outcoming method for extracting superthick oil |
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- 2007-05-16 BR BRPI0711475-3A patent/BRPI0711475A2/en not_active IP Right Cessation
- 2007-05-16 US US12/300,981 patent/US20090301704A1/en not_active Abandoned
- 2007-05-16 CA CA002652159A patent/CA2652159A1/en not_active Abandoned
- 2007-05-16 WO PCT/US2007/069027 patent/WO2007137061A2/en active Application Filing
- 2007-05-16 CN CN200780023198.3A patent/CN101484662B/en not_active Expired - Fee Related
- 2007-05-16 EA EA200870537A patent/EA018256B1/en not_active IP Right Cessation
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| WO2007137061A3 (en) | 2008-11-13 |
| CN101484662B (en) | 2013-06-19 |
| CN101484662A (en) | 2009-07-15 |
| BRPI0711475A2 (en) | 2012-08-14 |
| WO2007137061A2 (en) | 2007-11-29 |
| EA200870537A1 (en) | 2009-04-28 |
| EA018256B1 (en) | 2013-06-28 |
| US20090301704A1 (en) | 2009-12-10 |
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| EEER | Examination request | ||
| FZDE | Discontinued |
Effective date: 20160914 |