National Library of Energy BETA

Sample records for gas reservoirs cxs

  1. Carbon sequestration in natural gas reservoirs: Enhanced gas recovery and natural gas storage

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2003-01-01

    cushion gas for natural gas storage, Energy and Fuels, 17(RECOVERY AND NATURAL GAS STORAGE Curtis M. Oldenburg Eartheffective cushion gas for gas storage reservoirs. Thus at

  2. Underground natural gas storage reservoir management

    SciTech Connect (OSTI)

    Ortiz, I.; Anthony, R.

    1995-06-01

    The objective of this study is to research technologies and methodologies that will reduce the costs associated with the operation and maintenance of underground natural gas storage. This effort will include a survey of public information to determine the amount of natural gas lost from underground storage fields, determine the causes of this lost gas, and develop strategies and remedial designs to reduce or stop the gas loss from selected fields. Phase I includes a detailed survey of US natural gas storage reservoirs to determine the actual amount of natural gas annually lost from underground storage fields. These reservoirs will be ranked, the resultant will include the amount of gas and revenue annually lost. The results will be analyzed in conjunction with the type (geologic) of storage reservoirs to determine the significance and impact of the gas loss. A report of the work accomplished will be prepared. The report will include: (1) a summary list by geologic type of US gas storage reservoirs and their annual underground gas storage losses in ft{sup 3}; (2) a rank by geologic classifications as to the amount of gas lost and the resultant lost revenue; and (3) show the level of significance and impact of the losses by geologic type. Concurrently, the amount of storage activity has increased in conjunction with the net increase of natural gas imports as shown on Figure No. 3. Storage is playing an ever increasing importance in supplying the domestic energy requirements.

  3. Carbon sequestration in natural gas reservoirs: Enhanced gas recovery and natural gas storage

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2003-01-01

    gas reservoirs for carbon sequestration and enhanced gasproduction and carbon sequestration, Society of Petroleumfeasibiilty of carbon sequestration with enhanced gas

  4. Variations in dissolved gas compositions of reservoir fluids...

    Open Energy Info (EERE)

    reservoir in its natural state. Two geographically distinct regions of single-phase (liquid) reservoir are present and possess distinctive gas and liquid compositions....

  5. Geomechanical Development of Fractured Reservoirs During Gas Production 

    E-Print Network [OSTI]

    Huang, Jian

    2013-04-05

    Within fractured reservoirs, such as tight gas reservoir, coupled processes between matrix deformation and fluid flow are very important for predicting reservoir behavior, pore pressure evolution and fracture closure. To study the coupling between...

  6. EIA - Natural Gas Pipeline Network - Salt Cavern Storage Reservoir...

    U.S. Energy Information Administration (EIA) Indexed Site

    Salt Cavern Storage Reservoir Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 20072008 with selected updates Salt Cavern...

  7. EIA - Natural Gas Pipeline Network - Depleted Reservoir Storage...

    Gasoline and Diesel Fuel Update (EIA)

    Depleted Reservoir Storage Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 20072008 with selected updates Depleted Production...

  8. EIA - Natural Gas Pipeline Network - Aquifer Storage Reservoir...

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    Aquifer Storage Reservoir Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 20072008 with selected updates Aquifer Underground...

  9. Feasibility of waterflooding Soku E7000 gas-condensate reservoir 

    E-Print Network [OSTI]

    Ajayi, Arashi

    2002-01-01

    We performed a simple 3D compositional reservoir simulation study to examine the possibility of waterflooding the Soku E7 gas-condensate reservoir. This study shows that water injection results in higher condensate recovery than natural depletion...

  10. Reservoir Engineering for Unconventional Gas Reservoirs: What Do We Have to Consider?

    SciTech Connect (OSTI)

    Clarkson, Christopher R

    2011-01-01

    The reservoir engineer involved in the development of unconventional gas reservoirs (UGRs) is required to integrate a vast amount of data from disparate sources, and to be familiar with the data collection and assessment. There has been a rapid evolution of technology used to characterize UGR reservoir and hydraulic fracture properties, and there currently are few standardized procedures to be used as guidance. Therefore, more than ever, the reservoir engineer is required to question data sources and have an intimate knowledge of evaluation procedures. We propose a workflow for the optimization of UGR field development to guide discussion of the reservoir engineer's role in the process. Critical issues related to reservoir sample and log analysis, rate-transient and production data analysis, hydraulic and reservoir modeling and economic analysis are raised. Further, we have provided illustrations of each step of the workflow using tight gas examples. Our intent is to provide some guidance for best practices. In addition to reviewing existing methods for reservoir characterization, we introduce new methods for measuring pore size distribution (small-angle neutron scattering), evaluating core-scale heterogeneity, log-core calibration, evaluating core/log data trends to assist with scale-up of core data, and modeling flow-back of reservoir fluids immediately after well stimulation. Our focus in this manuscript is on tight and shale gas reservoirs; reservoir characterization methods for coalbed methane reservoirs have recently been discussed.

  11. A Variable Cell Model for Simulating Gas Condensate Reservoir Performance

    E-Print Network [OSTI]

    Al-Majed, Abdulaziz Abdullah

    , SPE-~~~ SPE 21428 A Variable Cell Model for Simulating Gas Condensate Reservoir Performance A of depletion performance of gas condensate reservoirs report the existence of a A variable cell model for simulating gas relatively high, near-constant, oil saturation in condensate reeervoir performance has been

  12. ,"New Mexico Dry Natural Gas New Reservoir Discoveries in Old...

    U.S. Energy Information Administration (EIA) Indexed Site

    Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","New Mexico Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic...

  13. ,"Texas Dry Natural Gas New Reservoir Discoveries in Old Fields...

    U.S. Energy Information Administration (EIA) Indexed Site

    ,"Worksheet Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","Texas Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic...

  14. Horizontal Well Placement Optimization in Gas Reservoirs Using Genetic Algorithms 

    E-Print Network [OSTI]

    Gibbs, Trevor Howard

    2011-08-08

    saturation and believed to be a volumetric reservoir with no water drive. The reservoir temperature is at 275 deg F. The gas gravity, relative density to air, is 0.68, and the permeability of the gas reservoir is 0.1 md. Case-specific differences... PLACEMENT OPTIMIZATION IN GAS RESERVOIRS USING GENETIC ALGORITHMS A Thesis by TREVOR HOWARD GIBBS Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER...

  15. New inflow performance relationships for gas condensate reservoirs 

    E-Print Network [OSTI]

    Del Castillo Maravi, Yanil

    2004-09-30

    - similar to the Vogel IPR trends (the Vogel (quadratic) rate-pressure profile is generally presumed for the case of a solution gas-drive reservoir system). However, in the case of a gas-condensate reservoir system, the coefficients in the quadratic...

  16. AN ADVISORY SYSTEM FOR THE DEVELOPMENT OF UNCONVENTIONAL GAS RESERVOIRS 

    E-Print Network [OSTI]

    Wei, Yunan

    2010-01-16

    With the rapidly increasing demand for energy and the increasing prices for oil and gas, the role of unconventional gas reservoirs (UGRs) as energy sources is becoming more important throughout the world. Because of high risks and uncertainties...

  17. Modeling well performance in compartmentalized gas reservoirs 

    E-Print Network [OSTI]

    Yusuf, Nurudeen

    2008-10-10

    for consolidated reservoir cases while synthetic data (generated by the model using known parameters) was used for unconsolidated reservoir cases. In both cases, the Compartmentalized Depletion Model was used to analyze data, and estimate the OGIP and Jg of each...

  18. Modeling well performance in compartmentalized gas reservoirs 

    E-Print Network [OSTI]

    Yusuf, Nurudeen

    2009-05-15

    and performance characteristics of each compartment in such reservoirs given production data. A geomechanics model was developed using available correlation in the industry to estimate variable pore volume compressibility, reservoir compaction and permeability...

  19. Joule-Thomson Cooling Due to CO2 Injection into Natural Gas Reservoirs

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2006-01-01

    cushion gas for natural gas storage, Energy & Fuels, 17(1),cushion gas for natural gas storage (Oldenburg, 2003). Forstorage of carbon dioxide in depleted natural gas reservoirs

  20. Stress-dependent permeability on tight gas reservoirs 

    E-Print Network [OSTI]

    Rodriguez, Cesar Alexander

    2005-02-17

    People in the oil and gas industry sometimes do not consider pressure-dependent permeability in reservoir performance calculations. It basically happens due to lack of lab data to determine level of dependency. This thesis attempts to evaluate...

  1. Analysis of Water Flowback Data in Gas Shale Reservoirs 

    E-Print Network [OSTI]

    Aldaif, Hussain

    2014-09-24

    Properties of both shale gas reservoirs and hydraulic fractures are usually estimated by analyzing hydrocarbon production data while water data is typically ignored. This study introduces a new method to estimate the effective fracture volume...

  2. Analysis of a geopressured gas reservoir using solution plot method 

    E-Print Network [OSTI]

    Hussain, Syed Muqeedul

    1992-01-01

    ANALYSIS OF A GEOPRESSURED GAS RESERVOIR USING SOLUTION PLOT METHOD A Thesis by SYED MUQEEDUL HUSSAIN Submitted to the Office of Cuaduate Studies of Texas ARM University in partial fulfillment of the requirements for the degree of MASTER... OF SCIENCE December 1992 Major Subject: Petroleum Engineering ANALYSIS OF A GEOPRESSURED GAS RESERVOIR USING SOLUTION PLOT METHOD A Thesis by SYED MUQEEDUL HUSSAIN Approved as to style and content by: S. W. Poston (Chair of Committee) R. R. Berg...

  3. Recovery of oil from fractured reservoirs by gas displacement 

    E-Print Network [OSTI]

    Unneberg, Arild

    1974-01-01

    RECOVERY OF OIL FROM FRACTURED RESERVOIRS BY GAS DISPLACEMENT A Thesis by ARILD UNNE BE RG Submitted to the Graduate College of Texas AlkM University in partial fulfillment of the requirement for the degree of MASTER OF SCIENCE August 1974... Major Subject: Petroleum Engineering RECOVERY OF OIL FROM FRACTURED RESERVOIRS BY GAS DISPLACEMENT A Thesis by ARILD UNNEBERG Approved as, to style and content by: . ( y (Chairman of Cornrnittee) (Head of Depar nt) / (Membe r) (Member) M b...

  4. US production of natural gas from tight reservoirs

    SciTech Connect (OSTI)

    Not Available

    1993-10-18

    For the purposes of this report, tight gas reservoirs are defined as those that meet the Federal Energy Regulatory Commission`s (FERC) definition of tight. They are generally characterized by an average reservoir rock permeability to gas of 0.1 millidarcy or less and, absent artificial stimulation of production, by production rates that do not exceed 5 barrels of oil per day and certain specified daily volumes of gas which increase with the depth of the reservoir. All of the statistics presented in this report pertain to wells that have been classified, from 1978 through 1991, as tight according to the FERC; i.e., they are ``legally tight`` reservoirs. Additional production from ``geologically tight`` reservoirs that have not been classified tight according to the FERC rules has been excluded. This category includes all producing wells drilled into legally designated tight gas reservoirs prior to 1978 and all producing wells drilled into physically tight gas reservoirs that have not been designated legally tight. Therefore, all gas production referenced herein is eligible for the Section 29 tax credit. Although the qualification period for the credit expired at the end of 1992, wells that were spudded (began to be drilled) between 1978 and May 1988, and from November 5, 1990, through year end 1992, are eligible for the tax credit for a subsequent period of 10 years. This report updates the EIA`s tight gas production information through 1991 and considers further the history and effect on tight gas production of the Federal Government`s regulatory and tax policy actions. It also provides some high points of the geologic background needed to understand the nature and location of low-permeability reservoirs.

  5. Analyzing aquifers associated with gas reservoirs using aquifer influence functions 

    E-Print Network [OSTI]

    Targac, Gary Wayne

    1988-01-01

    ANALYZING AQUIFERS ASSOCIATED WITH GAS RESERVOIRS USING AQUIFER INFLUENCE FUNCTIONS A Thesis by GARY WAYNE TARGAC Submitted to the Graduate College of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER... OF SCIENCE V z May 1988 z V z z I- Major Subject: Petroleum Engineering ANALYZING AQUIFERS ASSOCIATED WITH GAS RESERVOIRS USING AQUIFER INFLUENCE FUNCTIONS A Thesis by GARY WAYNE TARGAC Approved as to style and content by: (Chair of Committ R...

  6. Integrated Multi-Well Reservoir and Decision Model to Determine Optimal Well Spacing in Unconventional Gas Reservoirs 

    E-Print Network [OSTI]

    Ortiz Prada, Rubiel Paul

    2012-02-14

    Optimizing well spacing in unconventional gas reservoirs is difficult due to complex heterogeneity, large variability and uncertainty in reservoir properties, and lack of data that increase the production uncertainty. Previous methods are either...

  7. Joule-Thomson Cooling Due to CO2 Injection into Natural Gas Reservoirs

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2006-01-01

    dioxide in depleted natural gas reservoirs and in uselessHydrogen production from natural gas, sequestration ofas cushion gas for natural gas storage, Energy & Fuels, 17(

  8. The effects of production rates and some reservoir parameters on recovery in a strong water drive gas reservoir 

    E-Print Network [OSTI]

    Soemarso, Christophorus

    1978-01-01

    THE EFFECTS OF PRODUCTION RATES AND SOME RESERVOIR PARAMETERS ON RECOVERY IN A STRONG WATER DRIVE GAS RESERVOIR A Thesis by CHRISTOPHORUS SOEMARSO Submitted to the Graduate College of Texas A&M University in partial fulfillment... of the requirement for the degree of MASTER OF SCIENCE December 1978 Major Subject: Petroleum Engineering THE EFFECTS OF PRODUCTION RATES AND SOME RESERVOIR PARAMETERS ON RECOVERY IN A STRONG WATER DRIVE GAS RESERVOIR A Thesis by CHRISTOPHORUS SOEMARSO...

  9. Improved Upscaling & Well Placement Strategies for Tight Gas Reservoir Simulation and Management 

    E-Print Network [OSTI]

    Zhou, Yijie

    2013-07-29

    , with opportunities for improved reservoir simulation & management, such as simulation model design, well placement. Our work develops robust and efficient strategies for improved tight gas reservoir simulation and management. Reservoir simulation models are usually...

  10. Integrated Hydraulic Fracture Placement and Design Optimization in Unconventional Gas Reservoirs 

    E-Print Network [OSTI]

    Ma, Xiaodan

    2013-12-10

    Unconventional reservoir such as tight and shale gas reservoirs has the potential of becoming the main source of cleaner energy in the 21th century. Production from these reservoirs is mainly accomplished through engineered hydraulic fracturing...

  11. Using multi-layer models to forecast gas flow rates in tight gas reservoirs 

    E-Print Network [OSTI]

    Jerez Vera, Sergio Armando

    2007-04-25

    USING MULTI-LAYER MODELS TO FORECAST GAS FLOW RATES IN TIGHT GAS RESERVOIRS A Thesis by SERGIO ARMANDO JEREZ VERA Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements... for the degree of MASTER OF SCIENCE December 2006 Major Subject: Petroleum Engineering USING MULTI-LAYER MODELS TO FORECAST GAS FLOW RATES IN TIGHT GAS RESERVOIRS A Thesis by SERGIO ARMANDO JEREZ VERA Submitted...

  12. Accounting for Adsorbed gas and its effect on production bahavior of Shale Gas Reservoirs 

    E-Print Network [OSTI]

    Mengal, Salman Akram

    2010-10-12

    FOR ADSORBED GAS AND ITS EFFECT ON PRODUCTION BEHAVIOR OF SHALE GAS RESERVOIRS A Thesis by SALMAN AKRAM MENGAL Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements for the degree... of MASTER OF SCIENCE August 2010 Major Subject: Petroleum Engineering ACCOUNTING FOR ADSORBED GAS AND ITS EFFECT ON PRODUCTION BEHAVIOR OF SHALE GAS RESERVOIRS A Thesis by SALMAN AKRAM MENGAL Submitted to the Office...

  13. Numerical modeling of self-limiting and self-enhancing caprock alteration induced by CO2 storage in a depleted gas reservoir

    E-Print Network [OSTI]

    Gherardi, Fabrizio

    2008-01-01

    under different reservoir gas saturation initial conditions.to initial reservoir gas saturation has been explored, anddone for initial reservoir gas saturations varying from 0.1

  14. Application of the Continuous EUR Method to Estimate Reserves in Unconventional Gas Reservoirs 

    E-Print Network [OSTI]

    Currie, Stephanie M.

    2010-10-12

    for unconventional gas reservoirs using a rate-time analysis approach. This work offers a coherent process to reduce the uncertainty in reserves estimation for unconventional gas reservoirs by quantifying "upper" and "lower" limits of EUR prior to the onset...

  15. Developing a tight gas sand advisor for completion and stimulation in tight gas reservoirs worldwide 

    E-Print Network [OSTI]

    Bogatchev, Kirill Y.

    2009-05-15

    and experience about completion and stimulation technologies used in TGS reservoirs. We developed the principal design and two modules of a computer program called Tight Gas Sand Advisor (TGS Advisor), which can be used to assist engineers in making decisions...

  16. Application of Fast Marching Method in Shale Gas Reservoir Model Calibration 

    E-Print Network [OSTI]

    Yang, Changdong

    2013-07-26

    and reservoir heterogeneity but also is time consuming. In this thesis, we propose and apply an efficient technique, fast marching method (FMM), to analyze the shale gas reservoirs. Our proposed approach stands midway between analytic techniques and numerical...

  17. Experimental Investigation of Propped Fracture Conductivity in Tight Gas Reservoirs Using The Dynamic Conductivity Test 

    E-Print Network [OSTI]

    Romero Lugo, Jose 1985-

    2012-10-24

    Hydraulic Fracturing stimulation technology is used to increase the amount of oil and gas produced from low permeability reservoirs. The primary objective of the process is to increase the conductivity of the reservoir by the creation of fractures...

  18. A Novel Approach For the Simulation of Multiple Flow Mechanisms and Porosities in Shale Gas Reservoirs 

    E-Print Network [OSTI]

    Yan, Bicheng

    2013-07-15

    The state of the art of modeling fluid flow in shale gas reservoirs is dominated by dual porosity models that divide the reservoirs into matrix blocks that significantly contribute to fluid storage and fracture networks which principally control...

  19. EOS7C Version 1.0: TOUGH2 Module for Carbon Dioxide or Nitrogen in Natural Gas (Methane) Reservoirs

    E-Print Network [OSTI]

    Oldenburg, Curtis M.; Moridis, George J.; Spycher, Nicholas; Pruess, Karsten

    2004-01-01

    as cushion gas for natural gas storage, Energy&Fuels ,of CO 2 injection into natural gas reservoirs for carbonDioxide or Nitrogen in Natural Gas (Methane) Reservoirs

  20. The Performance of Fractured Horizontal Well in Tight Gas Reservoir 

    E-Print Network [OSTI]

    Lin, Jiajing

    2012-02-14

    Horizontal wells have been used to increase reservoir recovery, especially in unconventional reservoirs, and hydraulic fracturing has been applied to further extend the contact with the reservoir to increase the efficiency of development...

  1. A combined saline formation and gas reservoir CO2 injection pilot in Northern California

    E-Print Network [OSTI]

    Trautz, Robert; Myer, Larry; Benson, Sally; Oldenburg, Curt; Daley, Thomas; Seeman, Ed

    2006-01-01

    the middle Capay Shale (depleted gas) and McCormick Sand (depleted gas reservoir located within the Middle Capay shaleCO 2 gas will occur in the 2-3 m thick Capay Shale interval

  2. Paper #194973 GEOCHEMICAL CHARACTERIZATION OF THE RESERVOIR HOSTING SHALE-GAS AND OIL in

    E-Print Network [OSTI]

    Hattori, Kéiko H.

    Paper #194973 GEOCHEMICAL CHARACTERIZATION OF THE RESERVOIR HOSTING SHALE-GAS AND OIL a reservoir for shale-gas and oil. We examined organic-rich black shale, known as Macasty shale, of Upper SHALE-GAS AND OIL in THE SUBSURFACE OF ANTICOSTI ISLAND, CANADA Key Words: Provenance, Anticosti Island

  3. Pore-scale mechanisms of gas flow in tight sand reservoirs

    E-Print Network [OSTI]

    Silin, D.

    2011-01-01

    a homoge- neous reservoir the condensate saturation will bewater saturation distribution in a tight gas sand reservoirreservoir, the accumulating condensate can become mobile after reaching a certain saturation

  4. Importance of Low Permeability Natural Gas Reservoirs (released in AEO2010)

    Reports and Publications (EIA)

    2010-01-01

    Production from low-permeability reservoirs, including shale gas and tight gas, has become a major source of domestic natural gas supply. In 2008, low-permeability reservoirs accounted for about 40% of natural gas production and about 35% of natural gas consumption in the United States. Permeability is a measure of the rate at which liquids and gases can move through rock. Low-permeability natural gas reservoirs encompass the shale, sandstone, and carbonate formations whose natural permeability is roughly 0.1 millidarcies or below. (Permeability is measured in darcies.)

  5. Advanced Hydraulic Fracturing Technology for Unconventional Tight Gas Reservoirs

    SciTech Connect (OSTI)

    Stephen Holditch; A. Daniel Hill; D. Zhu

    2007-06-19

    The objectives of this project are to develop and test new techniques for creating extensive, conductive hydraulic fractures in unconventional tight gas reservoirs by statistically assessing the productivity achieved in hundreds of field treatments with a variety of current fracturing practices ranging from 'water fracs' to conventional gel fracture treatments; by laboratory measurements of the conductivity created with high rate proppant fracturing using an entirely new conductivity test - the 'dynamic fracture conductivity test'; and by developing design models to implement the optimal fracture treatments determined from the field assessment and the laboratory measurements. One of the tasks of this project is to create an 'advisor' or expert system for completion, production and stimulation of tight gas reservoirs. A central part of this study is an extensive survey of the productivity of hundreds of tight gas wells that have been hydraulically fractured. We have been doing an extensive literature search of the SPE eLibrary, DOE, Gas Technology Institute (GTI), Bureau of Economic Geology and IHS Energy, for publicly available technical reports about procedures of drilling, completion and production of the tight gas wells. We have downloaded numerous papers and read and summarized the information to build a database that will contain field treatment data, organized by geographic location, and hydraulic fracture treatment design data, organized by the treatment type. We have conducted experimental study on 'dynamic fracture conductivity' created when proppant slurries are pumped into hydraulic fractures in tight gas sands. Unlike conventional fracture conductivity tests in which proppant is loaded into the fracture artificially; we pump proppant/frac fluid slurries into a fracture cell, dynamically placing the proppant just as it occurs in the field. From such tests, we expect to gain new insights into some of the critical issues in tight gas fracturing, in particular the roles of gel damage, polymer loading (water-frac versus gel frac), and proppant concentration on the created fracture conductivity. To achieve this objective, we have designed the experimental apparatus to conduct the dynamic fracture conductivity tests. The experimental apparatus has been built and some preliminary tests have been conducted to test the apparatus.

  6. SHEAR WAVE TIME-LAPSE SEISMIC MONITORING OF A TIGHT GAS SANDSTONE RESERVOIR, RULISON FIELD, COLORADO

    E-Print Network [OSTI]

    SHEAR WAVE TIME-LAPSE SEISMIC MONITORING OF A TIGHT GAS SANDSTONE RESERVOIR, RULISON FIELD focused specifically on the use of time-lapse (4D) poststack migrated shear-wave seismic data of shear wave data as a tool for monitoring 4D changes. The basin centered tight gas sandstone reservoir

  7. New Advances in Shale Gas Reservoir Analysis Using Water Flowback Data 

    E-Print Network [OSTI]

    Alkouh, Ahmad

    2014-04-04

    Shale gas reservoirs with multistage hydraulic fractures are commonly characterized by analyzing long-term gas production data, but water flowback data is usually not included in the analysis. However, this work shows there can be benefits...

  8. The construction and use of aquifer influence functions in determining original gas in place for water-drive gas reservoirs 

    E-Print Network [OSTI]

    Gajdica, Ronald Joseph

    1986-01-01

    THE CONSTRUCTION AND USE OF AQUIFER INFLUENCE FUNCTIONS IN DETERMINING ORIGINAL GAS IN PLACE FOR WATER-DRIVE GAS RESERVOIRS A Thesis by RONALD JOSEPH GAJDICA Submitted to the Graduate College of Texas A&M University in partial fulfillment... of the requirements for the degree of MASTER OF SCIENCE December 1986 Major Subject: Petroleum Engineering THE CONSTRUCTION AND USE OF AQUIFER INFLUENCE FUNCTIONS IN DETERMINING ORIGINAL GAS IN PLACE FOR MATER-DRIVE GAS RESERVOIRS A Thesis by RONALD JOSEPH...

  9. Case history of pressure maintenance by gas injection in the 26R gravity drainage reservoir

    SciTech Connect (OSTI)

    Wei, M.H.; Yu, J.P.; Moore, D.M.; Ezekwe, N. (Bechtel Petroleum Operations, Inc., Tupman, CA (United States)); Querin, M.E. (USDOE Naval Petroleum Reserves in California, Tupman, CA (United States)); Williams, L.L. (Chevron U.S.A., Inc., San Francisco, CA (United States))

    1992-01-01

    This paper is a field case history on the performance of the 26R Reservoir. This is a gravity drainage reservoir under pressure maintenance by crestal gas injection. The 26R Reservoir is a highly layered Stevens turbidite sandstone. The reservoir is located in the Naval Petroleum Reserve No. 1 (NPR{number sign}1) in Elk Hills, Kern County, California. The 26R Reservoir is contained within the steeply dipping southwestern limb of the 31S Anticline. The reservoir had an initial oil column of 1800 feet. Original oil-in-place (OOIP) was estimated at 424 million barrels. Pressure maintenance by crestal gas injection was initiated immediately after production began in October 1976. The total volume of gas injected is about 586 BCF. This exceeds one reservoir pore volume. Reservoir pressure has declined from 3030 psi to 2461 psi. This pressure decline believe to be due to migration of injected gas into the overlaying shale reservoirs. Under the gas injection pressure maintenance strategy, reserves are estimated to be approximately 212 million barrels. Reservoir studies have concluded that the aquifer at the base of the reservoir has been relatively inactive. Well recompletions, deepenings, and horizontal wells are used to improve oil recovery. An aggressive program of controlling gas production began in the mid 1980's by the installation of multiple packers and sleeves. As the gas-oil contact (GOC) has dropped, sand intervals have subsequently been isolated behind packers. A cased hole logging program was recently undertaken to identify possible remaining reserves in the gas cap. 15 refs., 24 figs., 2 tabs.

  10. Case history of pressure maintenance by gas injection in the 26R gravity drainage reservoir

    SciTech Connect (OSTI)

    Wei, M.H.; Yu, J.P.; Moore, D.M.; Ezekwe, N. [Bechtel Petroleum Operations, Inc., Tupman, CA (United States); Querin, M.E. [USDOE Naval Petroleum Reserves in California, Tupman, CA (United States); Williams, L.L. [Chevron U.S.A., Inc., San Francisco, CA (United States)

    1992-02-01

    This paper is a field case history on the performance of the 26R Reservoir. This is a gravity drainage reservoir under pressure maintenance by crestal gas injection. The 26R Reservoir is a highly layered Stevens turbidite sandstone. The reservoir is located in the Naval Petroleum Reserve No. 1 (NPR{number_sign}1) in Elk Hills, Kern County, California. The 26R Reservoir is contained within the steeply dipping southwestern limb of the 31S Anticline. The reservoir had an initial oil column of 1800 feet. Original oil-in-place (OOIP) was estimated at 424 million barrels. Pressure maintenance by crestal gas injection was initiated immediately after production began in October 1976. The total volume of gas injected is about 586 BCF. This exceeds one reservoir pore volume. Reservoir pressure has declined from 3030 psi to 2461 psi. This pressure decline believe to be due to migration of injected gas into the overlaying shale reservoirs. Under the gas injection pressure maintenance strategy, reserves are estimated to be approximately 212 million barrels. Reservoir studies have concluded that the aquifer at the base of the reservoir has been relatively inactive. Well recompletions, deepenings, and horizontal wells are used to improve oil recovery. An aggressive program of controlling gas production began in the mid 1980`s by the installation of multiple packers and sleeves. As the gas-oil contact (GOC) has dropped, sand intervals have subsequently been isolated behind packers. A cased hole logging program was recently undertaken to identify possible remaining reserves in the gas cap. 15 refs., 24 figs., 2 tabs.

  11. Modeling effects of diffusion and gravity drainage on oil recovery in naturally fractured reservoirs under gas injection

    E-Print Network [OSTI]

    Jamili, Ahmad

    2010-04-22

    Gas injection in naturally fractured reservoirs maintains the reservoir pressure, and increases oil recovery primarily by gravity drainage and to a lesser extent by mass transfer between the flowing gas in the fracture and the porous matrix...

  12. Characterization of oil and gas reservoirs and recovery technology deployment on Texas State Lands

    SciTech Connect (OSTI)

    Tyler, R.; Major, R.P.; Holtz, M.H.

    1997-08-01

    Texas State Lands oil and gas resources are estimated at 1.6 BSTB of remaining mobile oil, 2.1 BSTB, or residual oil, and nearly 10 Tcf of remaining gas. An integrated, detailed geologic and engineering characterization of Texas State Lands has created quantitative descriptions of the oil and gas reservoirs, resulting in delineation of untapped, bypassed compartments and zones of remaining oil and gas. On Texas State Lands, the knowledge gained from such interpretative, quantitative reservoir descriptions has been the basis for designing optimized recovery strategies, including well deepening, recompletions, workovers, targeted infill drilling, injection profile modification, and waterflood optimization. The State of Texas Advanced Resource Recovery program is currently evaluating oil and gas fields along the Gulf Coast (South Copano Bay and Umbrella Point fields) and in the Permian Basin (Keystone East, Ozona, Geraldine Ford and Ford West fields). The program is grounded in advanced reservoir characterization techniques that define the residence of unrecovered oil and gas remaining in select State Land reservoirs. Integral to the program is collaboration with operators in order to deploy advanced reservoir exploitation and management plans. These plans are made on the basis of a thorough understanding of internal reservoir architecture and its controls on remaining oil and gas distribution. Continued accurate, detailed Texas State Lands reservoir description and characterization will ensure deployment of the most current and economically viable recovery technologies and strategies available.

  13. Carbon sequestration in natural gas reservoirs: Enhanced gas recovery and natural gas storage

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2003-01-01

    Hydrogen production from natural gas, sequestration ofunderground storage of natural gas, Jour. Petrol. Tech. 943,dioxide as cushion gas for natural gas storage, Energy and

  14. Comparison of Single, Double, and Triple Linear Flow Models for Shale Gas/Oil Reservoirs 

    E-Print Network [OSTI]

    Tivayanonda, Vartit

    2012-10-19

    There have been many attempts to use mathematical method in order to characterize shale gas/oil reservoirs with multi-transverse hydraulic fractures horizontal well. Many authors have tried to come up with a suitable and practical mathematical model...

  15. Experimental and simulation studies of sequestration of supercritical carbon dioxide in depleted gas reservoirs 

    E-Print Network [OSTI]

    Seo, Jeong Gyu

    2004-09-30

    he feasibility of sequestering supercritical CO2 in depleted gas reservoirs. The experimental runs involved the following steps. First, the 1 ft long by 1 in. diameter carbonate core is inserted into a viton Hassler sleeve and placed inside...

  16. Analysis of condensate banking dynamics in a gas condensate reservoir under different injection schemes 

    E-Print Network [OSTI]

    Sandoval Rodriguez, Angelica Patricia

    2002-01-01

    condensate reservoir under natural depletion, and injection of methane, injection of carbon dioxide, produced gas recycling and water injection. To monitor the condensate banking dynamics near the wellbore area, such as oil saturation and compositional...

  17. Comparison of Various Deterministic Forecasting Techniques in Shale Gas Reservoirs with Emphasis on the Duong Method 

    E-Print Network [OSTI]

    Joshi, Krunal Jaykant

    2012-10-19

    There is a huge demand in the industry to forecast production in shale gas reservoirs accurately. There are many methods including volumetric, Decline Curve Analysis (DCA), analytical simulation and numerical simulation. Each one of these methods...

  18. A quadratic cumulative production model for the material balance of an abnormally pressured gas reservoir 

    E-Print Network [OSTI]

    Gonzalez, Felix Eduardo

    2005-02-17

    -1 A QUADRATIC CUMULATIVE PRODUCTION MODEL FOR THE MATERIAL BALANCE OF AN ABNORMALLY PRESSURED GAS RESERVOIR A Thesis by FELIX E. GONZALEZ ROMERO Submitted to the Office of Graduate Studies of Texas A&M University... OF AN ABNORMALLY PRESSURED GAS RESERVOIR A Thesis by FELIX E. GONZALEZ ROMERO Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER OF SCIENCE...

  19. The effects of production rate and gravitational segregation on gas injection performance of oil reservoirs 

    E-Print Network [OSTI]

    Ferguson, Ed Martin

    1972-01-01

    THE EFFECTS OF PRODUCTION RATE AND GRAVITATIONAL SEGREGATION ON GAS INJECTION PERFORMANCE OF OIL RESERVOIRS A Thesis by ED MARTIN FERGUSON Submitted to the Graduate College of Texas A&M University in partial fulfillment of the requirements... for the degree of MASTER OF SCIENCE August 1972 Major Subject: PETROLEUM ENGINEERING THE EFFECTS OF PRODUCTION RATE AND GRAVITATIONAL SEGREGATION ON GAS INJECTION PERFORMANCE OF OIL RESERVOIRS A Thesis by ED MARTIN FERGUSON Approved as. to style...

  20. The performance of a volatile oil reservoir overlain by a gas cap 

    E-Print Network [OSTI]

    Ellis, Joseph Ralph, Jr

    1960-01-01

    THE PERFORMANCE OF A VOLATILE OIL RESERVOIR OVERLAIN BY A GAS CAP A Thesis By J. RALPH ELLIS, JR. Submitted to the Graduate School of the Agricultural and Mechanical College of Texas in partial fulfillment of the requirements for the degree... of MASTER OF SCIENCE August, 1960 Major Subject: PETROLEUM ENGINEERING THE PERFORMANCE OF A VOLATILE OIL RESERVOIR OVERLAIN BY A GAS CAP A Thesis By J. RALPH ELLIS, JR. Approved as to style and content by: hairxnan of Coxnxnittee) (Head...

  1. Underground natural gas storage reservoir management: Phase 2. Final report, June 1, 1995--March 30, 1996

    SciTech Connect (OSTI)

    Ortiz, I.; Anthony, R.V.

    1996-12-31

    Gas storage operators are facing increased and more complex responsibilities for managing storage operations under Order 636 which requires unbundling of storage from other pipeline services. Low cost methods that improve the accuracy of inventory verification are needed to optimally manage this stored natural gas. Migration of injected gas out of the storage reservoir has not been well documented by industry. The first portion of this study addressed the scope of unaccounted for gas which may have been due to migration. The volume range was estimated from available databases and reported on an aggregate basis. Information on working gas, base gas, operating capacity, injection and withdrawal volumes, current and non-current revenues, gas losses, storage field demographics and reservoir types is contained among the FERC Form 2, EIA Form 191, AGA and FERC Jurisdictional databases. The key elements of this study show that gas migration can result if reservoir limits have not been properly identified, gas migration can occur in formation with extremely low permeability (0.001 md), horizontal wellbores can reduce gas migration losses and over-pressuring (unintentionally) storage reservoirs by reinjecting working gas over a shorter time period may increase gas migration effects.

  2. A New Type Curve Analysis for Shale Gas/Oil Reservoir Production Performance with Dual Porosity Linear System 

    E-Print Network [OSTI]

    Abdulal, Haider Jaffar

    2012-02-14

    With increase of interest in exploiting shale gas/oil reservoirs with multiple stage fractured horizontal wells, complexity of production analysis and reservoir description have also increased. Different methods and models were used throughout...

  3. Appraisal of transport and deformation in shale reservoirs using natural noble gas tracers

    SciTech Connect (OSTI)

    Heath, Jason E.; Kuhlman, Kristopher L.; Robinson, David G.; Bauer, Stephen J.; Gardner, William Payton

    2015-09-01

    This report presents efforts to develop the use of in situ naturally-occurring noble gas tracers to evaluate transport mechanisms and deformation in shale hydrocarbon reservoirs. Noble gases are promising as shale reservoir diagnostic tools due to their sensitivity of transport to: shale pore structure; phase partitioning between groundwater, liquid, and gaseous hydrocarbons; and deformation from hydraulic fracturing. Approximately 1.5-year time-series of wellhead fluid samples were collected from two hydraulically-fractured wells. The noble gas compositions and isotopes suggest a strong signature of atmospheric contribution to the noble gases that mix with deep, old reservoir fluids. Complex mixing and transport of fracturing fluid and reservoir fluids occurs during production. Real-time laboratory measurements were performed on triaxially-deforming shale samples to link deformation behavior, transport, and gas tracer signatures. Finally, we present improved methods for production forecasts that borrow statistical strength from production data of nearby wells to reduce uncertainty in the forecasts.

  4. Numerical simulation of the environmental impact of hydraulic fracturing of tight/shale gas reservoirs on near-surface groundwater: Background, base cases, shallow reservoirs, short-term gas, and water transport

    SciTech Connect (OSTI)

    Reagan, Matthew T.; Moridis, George J.; Keen, Noel D.; Johnson, Jeffrey N.

    2015-04-18

    Hydrocarbon production from unconventional resources and the use of reservoir stimulation techniques, such as hydraulic fracturing, has grown explosively over the last decade. However, concerns have arisen that reservoir stimulation creates significant environmental threats through the creation of permeable pathways connecting the stimulated reservoir with shallower freshwater aquifers, thus resulting in the contamination of potable groundwater by escaping hydrocarbons or other reservoir fluids. This study investigates, by numerical simulation, gas and water transport between a shallow tight-gas reservoir and a shallower overlying freshwater aquifer following hydraulic fracturing operations, if such a connecting pathway has been created. We focus on two general failure scenarios: (1) communication between the reservoir and aquifer via a connecting fracture or fault and (2) communication via a deteriorated, preexisting nearby well. We conclude that the key factors driving short-term transport of gas include high permeability for the connecting pathway and the overall volume of the connecting feature. Production from the reservoir is likely to mitigate release through reduction of available free gas and lowering of reservoir pressure, and not producing may increase the potential for release. We also find that hydrostatic tight-gas reservoirs are unlikely to act as a continuing source of migrating gas, as gas contained within the newly formed hydraulic fracture is the primary source for potential contamination. Such incidents of gas escape are likely to be limited in duration and scope for hydrostatic reservoirs. Reliable field and laboratory data must be acquired to constrain the factors and determine the likelihood of these outcomes.

  5. Advancing New 3D Seismic Interpretation Methods for Exploration and Development of Fractured Tight Gas Reservoirs

    SciTech Connect (OSTI)

    James Reeves

    2005-01-31

    In a study funded by the U.S. Department of Energy and GeoSpectrum, Inc., new P-wave 3D seismic interpretation methods to characterize fractured gas reservoirs are developed. A data driven exploratory approach is used to determine empirical relationships for reservoir properties. Fractures are predicted using seismic lineament mapping through a series of horizon and time slices in the reservoir zone. A seismic lineament is a linear feature seen in a slice through the seismic volume that has negligible vertical offset. We interpret that in regions of high seismic lineament density there is a greater likelihood of fractured reservoir. Seismic AVO attributes are developed to map brittle reservoir rock (low clay) and gas content. Brittle rocks are interpreted to be more fractured when seismic lineaments are present. The most important attribute developed in this study is the gas sensitive phase gradient (a new AVO attribute), as reservoir fractures may provide a plumbing system for both water and gas. Success is obtained when economic gas and oil discoveries are found. In a gas field previously plagued with poor drilling results, four new wells were spotted using the new methodology and recently drilled. The wells have estimated best of 12-months production indicators of 2106, 1652, 941, and 227 MCFGPD. The latter well was drilled in a region of swarming seismic lineaments but has poor gas sensitive phase gradient (AVO) and clay volume attributes. GeoSpectrum advised the unit operators that this location did not appear to have significant Lower Dakota gas before the well was drilled. The other three wells are considered good wells in this part of the basin and among the best wells in the area. These new drilling results have nearly doubled the gas production and the value of the field. The interpretation method is ready for commercialization and gas exploration and development. The new technology is adaptable to conventional lower cost 3D seismic surveys.

  6. General screening criteria for shale gas reservoirs and production data analysis of Barnett shale 

    E-Print Network [OSTI]

    Deshpande, Vaibhav Prakashrao

    2009-05-15

    Shale gas reservoirs are gaining importance in United States as conventional oil and gas resources are dwindling at a very fast pace. The purpose of this study is twofold. First aim is to help operators with simple screening criteria which can help...

  7. Carbon sequestration in natural gas reservoirs: Enhanced gas recovery and natural gas storage

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2003-01-01

    M. F. , Northern California oil and gas field production.California, Division of Oil, Gas and Geothermal Resources;Beaumont EA, eds. , Atlas of Oil and Gas Fields, Structural

  8. CO2-Driven Enhanced Gas Recovery and Storage in Depleted Shale Reservoir-A Numerical Simulation Study

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    1 CO2-Driven Enhanced Gas Recovery and Storage in Depleted Shale Reservoir- A Numerical Simulation for storage and enhanced gas recovery may be organic-rich shales, which CO2 is preferentially adsorbed comprehensive simulation studies to better understand CO2 injection process in shale gas reservoir. This paper

  9. Variations in dissolved gas compositions of reservoir fluids from the Coso geothermal field

    SciTech Connect (OSTI)

    Williams, Alan E.; Copp, John F.

    1991-01-01

    Gas concentrations and ratios in 110 analyses of geothermal fluids from 47 wells in the Coso geothermal system illustrate the complexity of this two-phase reservoir in its natural state. Two geographically distinct regions of single-phase (liquid) reservoir are present and possess distinctive gas and liquid compositions. Relationships in soluble and insoluble gases preclude derivation of these waters from a common parent by boiling or condensation alone. These two regions may represent two limbs of fluid migration away from an area of two-phase upwelling. During migration, the upwelling fluids mix with chemically evolved waters of moderately dissimilar composition. CO{sub 2} rich fluids found in the limb in the southeastern portion of the Coso field are chemically distinct from liquids in the northern limb of the field. Steam-rich portions of the reservoir also indicate distinctive gas compositions. Steam sampled from wells in the central and southwestern Coso reservoir is unusually enriched in both H{sub 2}S and H{sub 2}. Such a large enrichment in both a soluble and insoluble gas cannot be produced by boiling of any liquid yet observed in single-phase portions of the field. In accord with an upflow-lateral mixing model for the Coso field, at least three end-member thermal fluids having distinct gas and liquid compositions appear to have interacted (through mixing, boiling and steam migration) to produce the observed natural state of the reservoir.

  10. Dry gas zone, Elk Hills Field, Kern County, California: General reservoir study: Engineering data, effective August 1, 1988

    SciTech Connect (OSTI)

    Not Available

    1989-01-10

    This reservoir study of the dry gas zone of Elk Hills Field is a data compilation with information relating to well: completion; production; pressure; and back pressure. (JF)

  11. Impes modeling of volumetric dry gas reservoirs with mobile water 

    E-Print Network [OSTI]

    Forghany, Saeed

    2004-09-30

    ...................................................70 xi LIST OF TABLES TABLE Page 2.1 Averaging of parameters..........................................................................................14 3.1 Units for the PVT properties used in the input file... running the first subroutine in the time loop runs which takes care of reading reservoir, wells, PVT, relative permeabilities and all data required for the program to run from the input file. This subroutine is written in such a way that it is capable...

  12. Gas Flow Tightly Coupled to Elastoplastic Geomechanics for Tight- and Shale-Gas Reservoirs: Material Failure and Enhanced Permeability

    SciTech Connect (OSTI)

    Kim, Jihoon; Moridis, George

    2014-12-01

    We investigate coupled flow and geomechanics in gas production from extremely low permeability reservoirs such as tight and shale gas reservoirs, using dynamic porosity and permeability during numerical simulation. In particular, we take the intrinsic permeability as a step function of the status of material failure, and the permeability is updated every time step. We consider gas reservoirs with the vertical and horizontal primary fractures, employing the single and dynamic double porosity (dual continuum) models. We modify the multiple porosity constitutive relations for modeling the double porous continua for flow and geomechanics. The numerical results indicate that production of gas causes redistribution of the effective stress fields, increasing the effective shear stress and resulting in plasticity. Shear failure occurs not only near the fracture tips but also away from the primary fractures, which indicates generation of secondary fractures. These secondary fractures increase the permeability significantly, and change the flow pattern, which in turn causes a change in distribution of geomechanical variables. From various numerical tests, we find that shear failure is enhanced by a large pressure drop at the production well, high Biot's coefficient, low frictional and dilation angles. Smaller spacing between the horizontal wells also contributes to faster secondary fracturing. When the dynamic double porosity model is used, we observe a faster evolution of the enhanced permeability areas than that obtained from the single porosity model, mainly due to a higher permeability of the fractures in the double porosity model. These complicated physics for stress sensitive reservoirs cannot properly be captured by the uncoupled or flow-only simulation, and thus tightly coupled flow and geomechanical models are highly recommended to accurately describe the reservoir behavior during gas production in tight and shale gas reservoirs and to smartly design production scenarios.

  13. Effect of connate water on miscible displacement of reservoir oil by flue gas 

    E-Print Network [OSTI]

    Maxwell, H. D.

    1960-01-01

    EFFECT OF CONNATE WATER ON MISCIBLE DISPLACEMENT OF RESERVOIR OIL BY FLUE GAS A Thesis By H. D. MAXWELL, JR. Submitted to the Graduate School of the Agricultural and Mechanical College of Texas in partial fulfillment of the requirements... for the degree of MASTER OF SCIENCE Au gus t, 19 60 Major Subject: PETROLEUM ENGINEERING EFFECT OF CONNATE WATER ON MISCIBLE DISPLACEMENT OF RESERVOIR OIL BY FLUE GAS A Thesis H. D. MAXWELL, JR. Approved as to style and content by: haxrman of ommitte...

  14. GHG Emissions from Hydropower Reservoirs The role of hydropower reservoirs in contributing to greenhouse gas (GHG) emissions is poorly

    E-Print Network [OSTI]

    GHG Emissions from Hydropower Reservoirs The role of hydropower reservoirs in contributing from tropical and boreal reservoirs are significant. In light of hydropower's potential role as a green to characterize carbon dioxide (CO2) and methane (CH4) emissions from hydropower reservoirs in the US Southeast

  15. Discrete Fracture Reservoir Simulation

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Discrete Fracture Reservoir Simulation Shale Gas Flow Simulation Shale Gas Flow Simulation FRACGENNFFLOW, fractured reservoir modeling software developed by NETL's Geological and...

  16. Simulation of fracture fluid cleanup and its effect on long-term recovery in tight gas reservoirs 

    E-Print Network [OSTI]

    Wang, Yilin

    2009-05-15

    In the coming decades, the world will require additional supplies of natural gas to meet the demand for energy. Tight gas reservoirs can be defined as reservoirs where the formation permeability is so low (< 0.1 md) that advanced stimulation...

  17. Finite Element Solution of Nonlinear Transient Rock Damage with Application in Geomechanics of Oil and Gas Reservoirs

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    the geomechanics of oil and gas reservoirs. The fragile microstructure of some rocks makes it difficult to predict of Steel, Aluminum, Concrete, etc. Moreover, the pattern of rock damage in oil and gas reservoirsFinite Element Solution of Nonlinear Transient Rock Damage with Application in Geomechanics of Oil

  18. Characterization of Tight Gas Reservoir Pore Structure Using USANS/SANS and Gas Adsorption Analysis

    SciTech Connect (OSTI)

    Clarkson, Christopher R [ORNL; He, Lilin [ORNL; Agamalian, Michael [ORNL; Melnichenko, Yuri B [ORNL; Mastalerz, Maria [Indiana Geological Survey; Bustin, Mark [University of British Columbia, Vancouver; Radlinski, Andrzej Pawell [ORNL; Blach, Tomasz P [ORNL

    2012-01-01

    Small-angle and ultra-small-angle neutron scattering (SANS and USANS) measurements were performed on samples from the Triassic Montney tight gas reservoir in Western Canada in order to determine the applicability of these techniques for characterizing the full pore size spectrum and to gain insight into the nature of the pore structure and its control on permeability. The subject tight gas reservoir consists of a finely laminated siltstone sequence; extensive cementation and moderate clay content are the primary causes of low permeability. SANS/USANS experiments run at ambient pressure and temperature conditions on lithologically-diverse sub-samples of three core plugs demonstrated that a broad pore size distribution could be interpreted from the data. Two interpretation methods were used to evaluate total porosity, pore size distribution and surface area and the results were compared to independent estimates derived from helium porosimetry (connected porosity) and low-pressure N{sub 2} and CO{sub 2} adsorption (accessible surface area and pore size distribution). The pore structure of the three samples as interpreted from SANS/USANS is fairly uniform, with small differences in the small-pore range (< 2000 {angstrom}), possibly related to differences in degree of cementation, and mineralogy, in particular clay content. Total porosity interpreted from USANS/SANS is similar to (but systematically higher than) helium porosities measured on the whole core plug. Both methods were used to estimate the percentage of open porosity expressed here as a ratio of connected porosity, as established from helium adsorption, to the total porosity, as estimated from SANS/USANS techniques. Open porosity appears to control permeability (determined using pressure and pulse-decay techniques), with the highest permeability sample also having the highest percentage of open porosity. Surface area, as calculated from low-pressure N{sub 2} and CO{sub 2} adsorption, is significantly less than surface area estimates from SANS/USANS, which is due in part to limited accessibility of the gases to all pores. The similarity between N{sub 2} and CO{sub 2}-accessible surface area suggests an absence of microporosity in these samples, which is in agreement with SANS analysis. A core gamma ray profile run on the same core from which the core plug samples were taken correlates to profile permeability measurements run on the slabbed core. This correlation is related to clay content, which possibly controls the percentage of open porosity. Continued study of these effects will prove useful in log-core calibration efforts for tight gas.

  19. Effects of reservoir geometry and permeability anisotropy on ultimate gas recovery in Devonian Shale reservoirs 

    E-Print Network [OSTI]

    Starnes, Lee McKennon

    1989-01-01

    well spacing, k, =0. 1 md, k?=9k?, L, =50 feet, fracture perpendicular to k . 120 100 Comparison of cumulative gas production as a function of time with different drainage patterns, 160-acre well spacing, k, =0. 1 md, k?=9k?, Lr=100 feet, fracture... average permeabilities, 160-acre well spacing, k =25k?, Lr =100 feet, fracture perpendicular to k Comparison of cumulative gas production as a function of time with different fracture half-lengths, 160-acre well spacing, square drainage pattern, k, =0...

  20. Evaluation of Travis Peak gas reservoirs, west margin of the East Texas Basin 

    E-Print Network [OSTI]

    Li, Yamin

    2009-05-15

    produced gas since the 1940s. In this study, well log, 2D seismic, core, and production data were used to evaluate the geologic setting and reservoir characteristics of the Travis Peak formation. The primary objective was to assess the potential...

  1. 3-DIMENSIONAL GEOMECHANICAL MODELING OF A TIGHT GAS RESERVOIR, RULISON FIELD, PICEANCE BASIN, COLORADO

    E-Print Network [OSTI]

    3-DIMENSIONAL GEOMECHANICAL MODELING OF A TIGHT GAS RESERVOIR, RULISON FIELD, PICEANCE BASIN, COLORADO by Kurtis R. Wikel #12;ii #12;iii ABSTRACT An integrated 3-dimensional geomechanical model have used the predictive geomechanical model to compare production and effective stress change

  2. HIGH RESOLUTION PREDICTION OF GAS INJECTION PROCESS PERFORMANCE FOR HETEROGENEOUS RESERVOIRS

    SciTech Connect (OSTI)

    Franklin M. Orr, Jr.

    2002-12-31

    This report outlines progress in the first quarter of the third year of the DOE project ''High Resolution Prediction of Gas Injection Process Performance for Heterogeneous Reservoirs''. In this report we present an application of compositional streamline simulation in modeling enhanced condensate recovery via gas injection. These processes are inherently compositional and detailed compositional fluid descriptions must be use to represent the flow behavior accurately. Compositional streamline simulation results are compared to those of conventional finite-difference (FD) simulation for evaluation of gas injection schemes in condensate reservoirs. We present and compare streamline and FD results for two-dimensional (2D) and three-dimensional (3D) examples, to show that the compositional streamline method is a way to obtain efficiently estimates of reasonable accuracy for condensate recovery by gas injection.

  3. Numerical simulation of the environmental impact of hydraulic fracturing of tight/shale gas reservoirs on near-surface groundwater: Background, base cases, shallow reservoirs, short-term gas, and water transport: Simulation of Impact of Hydraulic Fracturing on Groundwater

    DOE Public Access Gateway for Energy & Science Beta (PAGES Beta)

    Reagan, Matthew T.; Moridis, George J.; Keen, Noel D.; Johnson, Jeffrey N.

    2015-04-18

    Hydrocarbon production from unconventional resources and the use of reservoir stimulation techniques, such as hydraulic fracturing, has grown explosively over the last decade. However, concerns have arisen that reservoir stimulation creates significant environmental threats through the creation of permeable pathways connecting the stimulated reservoir with shallower freshwater aquifers, thus resulting in the contamination of potable groundwater by escaping hydrocarbons or other reservoir fluids. This study investigates, by numerical simulation, gas and water transport between a shallow tight-gas reservoir and a shallower overlying freshwater aquifer following hydraulic fracturing operations, if such a connecting pathway has been created. We focus on twomore »general failure scenarios: (1) communication between the reservoir and aquifer via a connecting fracture or fault and (2) communication via a deteriorated, preexisting nearby well. We conclude that the key factors driving short-term transport of gas include high permeability for the connecting pathway and the overall volume of the connecting feature. Production from the reservoir is likely to mitigate release through reduction of available free gas and lowering of reservoir pressure, and not producing may increase the potential for release. We also find that hydrostatic tight-gas reservoirs are unlikely to act as a continuing source of migrating gas, as gas contained within the newly formed hydraulic fracture is the primary source for potential contamination. Such incidents of gas escape are likely to be limited in duration and scope for hydrostatic reservoirs. Reliable field and laboratory data must be acquired to constrain the factors and determine the likelihood of these outcomes.« less

  4. Numerical simulation of the environmental impact of hydraulic fracturing of tight/shale gas reservoirs on near-surface groundwater: Background, base cases, shallow reservoirs, short-term gas, and water transport

    DOE Public Access Gateway for Energy & Science Beta (PAGES Beta)

    Reagan, Matthew T.; Moridis, George J.; Keen, Noel D.; Johnson, Jeffrey N.

    2015-04-18

    Hydrocarbon production from unconventional resources and the use of reservoir stimulation techniques, such as hydraulic fracturing, has grown explosively over the last decade. However, concerns have arisen that reservoir stimulation creates significant environmental threats through the creation of permeable pathways connecting the stimulated reservoir with shallower freshwater aquifers, thus resulting in the contamination of potable groundwater by escaping hydrocarbons or other reservoir fluids. This study investigates, by numerical simulation, gas and water transport between a shallow tight-gas reservoir and a shallower overlying freshwater aquifer following hydraulic fracturing operations, if such a connecting pathway has been created. We focus on twomore »general failure scenarios: (1) communication between the reservoir and aquifer via a connecting fracture or fault and (2) communication via a deteriorated, preexisting nearby well. We conclude that the key factors driving short-term transport of gas include high permeability for the connecting pathway and the overall volume of the connecting feature. Production from the reservoir is likely to mitigate release through reduction of available free gas and lowering of reservoir pressure, and not producing may increase the potential for release. We also find that hydrostatic tight-gas reservoirs are unlikely to act as a continuing source of migrating gas, as gas contained within the newly formed hydraulic fracture is the primary source for potential contamination. Such incidents of gas escape are likely to be limited in duration and scope for hydrostatic reservoirs. Reliable field and laboratory data must be acquired to constrain the factors and determine the likelihood of these outcomes.« less

  5. Optimizing Development Strategies to Increase Reserves in Unconventional Gas Reservoirs 

    E-Print Network [OSTI]

    Turkarslan, Gulcan

    2011-10-21

    The ever increasing energy demand brings about widespread interest to rapidly, profitably and efficiently develop unconventional resources, among which tight gas sands hold a significant portion. However, optimization of development strategies...

  6. Selection of fracture fluid for stimulating tight gas reservoirs 

    E-Print Network [OSTI]

    Malpani, Rajgopal Vijaykumar

    2007-04-25

    Essentially all producing wells drilled in tight gas sands and shales are stimulated using hydraulic fracture treatments. The development of optimal fracturing procedures, therefore, has a large impact on the long-term economic viability...

  7. Geological characterization and 3D visualizations of the gas storage reservoir at Hillsboro field, Montgomery County, IL

    SciTech Connect (OSTI)

    Udegbunam, E.O.; Huff, B.G. [Illinois State Geological Survey, Champaign, IL (United States)

    1994-12-31

    Geological characterizations, modeling and 3-D computer-generated visualizations of the Ordovician St. Peter Sandstone at the Hillsboro Gas Storage field in Montgomery County, Illinois, are discussed. Petrophysical analyses reveal four distinct hydraulic flow units in six cored wells. Furthermore, four lithologies, identified by thin section petrography, are associated with the various hydraulic units. Fieldwide visualizations of 3-D distributions of petrophysically-derived attributes reservoir quality index (RQI) and flow zone indicator (FZI) -- show considerable vertical variability but lateral continuity. This finding explains why it is easier to expand the gas bubble laterally than vertically. Advantages of the 3-D reservoir description of Hillsboro Gas Storage field include (1) improved definition of the spatial porosity distribution which leads to better estimation of reservoir volumetrics; (2) improved definition of reservoir hydraulic flow zones; and (3) development of realistic reservoir model(s) for the simulation and management of the gas storage field.

  8. Integrated seismic study of naturally fractured tight gas reservoirs

    SciTech Connect (OSTI)

    Mavko, G.M.; Nur, A.

    1993-12-31

    Reflection seismic methods are, and will continue to be, the key geophysical tool for imaging these heterogeneities in the subsurface of the earth. However, in spite of great advances in field acquisition techniques and computer processing power, the primary product of conventional seismic work is still only the spatial pattern of reflectivity, which is a measure of velocity variations. Most of the amplitude information goes unused. Although fracture zones may have a reflectivity signature, more often they will not, because of steeply dipping angles, limited offset range in the acquisition, a subtle impedance mismatch, or too thin a fractured zone relative to the wavelength. In fact, there is probably no single seismic attribute that will always tell us what we need to know about fracture zones. Our objective, in the project, is to integrate the principles of rock physics into a quantitative interpretation scheme that exploits the broader spectrum of fracture zone signatures: anomalous compressional and shear wave velocities; Q and velocity dispersion; increased velocity anisotropy amplitude variation with offset (AVO) response. Our goal is to incorporate four key elements: Acquisition and processing of seismic reflection field data. Theoretical studies of the anisotropic signatures of fractured rocks. Laboratory measurements of seismic velocity, velocity anisotropy, and attenuation in reservoir and cap rocks. Integration and interpretation of seismic, well log, and laboratory data, incorporating forward modeling.

  9. Prediction of Gas Injection Performance for Heterogeneous Reservoirs

    SciTech Connect (OSTI)

    Blunt, M.J.; Orr, F.M. Jr.

    2001-03-26

    This report was an integrated study of the physics and chemistry affecting gas injection, from the pore scale to the field scale, and involved theoretical analysis, laboratory experiments and numerical simulation. Specifically, advances were made on streamline-based simulation, analytical solutions to 1D compositional displacements, and modeling and experimental measures of three-phase flow.

  10. EIA - Natural Gas Pipeline Network - Salt Cavern Storage Reservoir

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet) Wyoming963 1.969

  11. Potential hazards of compressed air energy storage in depleted natural gas reservoirs.

    SciTech Connect (OSTI)

    Cooper, Paul W.; Grubelich, Mark Charles; Bauer, Stephen J.

    2011-09-01

    This report is a preliminary assessment of the ignition and explosion potential in a depleted hydrocarbon reservoir from air cycling associated with compressed air energy storage (CAES) in geologic media. The study identifies issues associated with this phenomenon as well as possible mitigating measures that should be considered. Compressed air energy storage (CAES) in geologic media has been proposed to help supplement renewable energy sources (e.g., wind and solar) by providing a means to store energy when excess energy is available, and to provide an energy source during non-productive or low productivity renewable energy time periods. Presently, salt caverns represent the only proven underground storage used for CAES. Depleted natural gas reservoirs represent another potential underground storage vessel for CAES because they have demonstrated their container function and may have the requisite porosity and permeability; however reservoirs have yet to be demonstrated as a functional/operational storage media for compressed air. Specifically, air introduced into a depleted natural gas reservoir presents a situation where an ignition and explosion potential may exist. This report presents the results of an initial study identifying issues associated with this phenomena as well as possible mitigating measures that should be considered.

  12. CO2 utilization and storage in shale gas reservoirs: Experimental results and economic impacts

    DOE Public Access Gateway for Energy & Science Beta (PAGES Beta)

    Schaef, Herbert T.; Davidson, Casie L.; Owen, Antionette Toni; Miller, Quin R. S.; Loring, John S.; Thompson, Christopher J.; Bacon, Diana H.; Glezakou, Vassiliki Alexandra; McGrail, B. Peter

    2014-12-31

    Natural gas is considered a cleaner and lower-emission fuel than coal, and its high abundance from advanced drilling techniques has positioned natural gas as a major alternative energy source for the U.S. However, each ton of CO2 emitted from any type of fossil fuel combustion will continue to increase global atmospheric concentrations. One unique approach to reducing anthropogenic CO2 emissions involves coupling CO2 based enhanced gas recovery (EGR) operations in depleted shale gas reservoirs with long-term CO2 storage operations. In this paper, we report unique findings about the interactions between important shale minerals and sorbing gases (CH4 and CO2) andmore »associated economic consequences. Where enhanced condensation of CO2 followed by desorption on clay surface is observed under supercritical conditions, a linear sorption profile emerges for CH4. Volumetric changes to montmorillonites occur during exposure to CO2. Theory-based simulations identify interactions with interlayer cations as energetically favorable for CO2 intercalation. Thus, experimental evidence suggests CH4 does not occupy the interlayer and has only the propensity for surface adsorption. Mixed CH4:CO2 gas systems, where CH4 concentrations prevail, indicate preferential CO2 sorption as determined by in situ infrared spectroscopy and X-ray diffraction techniques. Collectively, these laboratory studies combined with a cost-based economic analysis provide a basis for identifying favorable CO2-EOR opportunities in previously fractured shale gas reservoirs approaching final stages of primary gas production. Moreover, utilization of site-specific laboratory measurements in reservoir simulators provides insight into optimum injection strategies for maximizing CH4/CO2 exchange rates to obtain peak natural gas production.« less

  13. Petrophysical Properties of Unconventional Low-Mobility Reservoirs (Shale Gas and Heavy Oil) by Using Newly Developed Adaptive Testing Approach

    E-Print Network [OSTI]

    Torres-Verdín, Carlos

    of SPE copyright. Abstract Pressure testing in very-low-mobility reservoirs is challengingSPE 159172 Petrophysical Properties of Unconventional Low-Mobility Reservoirs (Shale Gas and Heavy Oil) by Using Newly Developed Adaptive Testing Approach Hamid Hadibeik, The University of Texas

  14. Natural Gas Liquids New Reservoir Discoveries in Old Fields

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Marthrough 1996) in NevadaYear-Month802 827 788 811 831

  15. Nonassociated Natural Gas New Reservoir Discoveries in Old Fields, Wet

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Marthrough 1996)Price780Year JanYearFeet)19,981After Lease

  16. EIA - Natural Gas Pipeline Network - Aquifer Storage Reservoir

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet) Wyoming963 1.969 1.979Coal4Cubic43,728Configuration Aquifer Storage

  17. EIA - Natural Gas Pipeline Network - Depleted Reservoir Storage

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet) Wyoming963 1.969 1.979Coal4Cubic43,728Configuration Aquifer

  18. Dry Natural Gas New Reservoir Discoveries in Old Fields

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr May Jun Jul AugAdditions1-- -- -- --WO R K1,594

  19. Dry Natural Gas New Reservoir Discoveries in Old Fields (Summary)

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr May Jun Jul AugAdditions1-- -- -- --WO R K1,5942,598

  20. Mississippi Dry Natural Gas New Reservoir Discoveries in Old Fields

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr 2012DecadeTotal19 1522 35 42 44 46 287 5 7 12252

  1. Hydrolyzed Polyacrylamide- Polyethylenimine- Dextran Sulfate Polymer Gel System as a Water Shut-Off Agent in Unconventional Gas Reservoirs 

    E-Print Network [OSTI]

    Jayakumar, Swathika 1986-

    2012-07-09

    Technologies such as horizontal wells and multi-stage hydraulic fracturing have made ultra-low permeability shale and tight gas reservoirs productive but the industry is still on the learning curve when it comes to addressing ...

  2. The effects of fracture fluid cleanup upon the analysis of pressure buildup tests in tight gas reservoirs 

    E-Print Network [OSTI]

    Johansen, Atle Thomas

    1988-01-01

    THE EFFECTS OF FRACTURE FLUID CLEANUP UPON THE ANALYSIS OF PRESSURE BUILDUP TESTS IN TIGHT GAS RESERVOIRS A Thesis by ATLE THOMAS JOHANSEN Submitted to the Office of Graduate Studies of Texas ASM University in partial fulfillment... of the requirements for the degree of MASTER OF SCIENCE December 1988 Major Subject: Petroleum Engineering THE EFFECTS OF FRACTURE FLUID CLEANUP UPON THE ANALYSIS OF PRESSURE BUILDUP TESTS IN TIGHT GAS RESERVOIRS A Thesis by ATLE THOMAS JOHANSEN Approved...

  3. Predicting Well Stimulation Results in a Gas Storage Field in the Absence of Reservoir Data, Using Neural Networks

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    SPE 31159 Predicting Well Stimulation Results in a Gas Storage Field in the Absence of Reservoir of this methodology to a gas storage field is presented in this paper. The developed neural network can predict for future stimulation treatment in the aforementioned field. INTRODUCTION Gas storage fields have numerous

  4. Tritium Transport at the Rulison Site, a Nuclear-stimulated Low-permeability Natural Gas Reservoir

    SciTech Connect (OSTI)

    C. Cooper; M. Ye; J. Chapman

    2008-04-01

    The U.S. Department of Energy (DOE) and its predecessor agencies conducted a program in the 1960s and 1970s that evaluated technology for the nuclear stimulation of low-permeability natural gas reservoirs. The second project in the program, Project Rulison, was located in west-central Colorado. A 40-kiltoton nuclear device was detonated 2,568 m below the land surface in the Williams Fork Formation on September 10, 1969. The natural gas reservoirs in the Williams Fork Formation occur in low permeability, fractured sandstone lenses interbedded with shale. Radionuclides derived from residual fuel products, nuclear reactions, and activation products were generated as a result of the detonation. Most of the radionuclides are contained in a cooled, solidified melt glass phase created from vaporized and melted rock that re-condensed after the test. Of the mobile gas-phase radionuclides released, tritium ({sup 3}H or T) migration is of most concern. The other gas-phase radionuclides ({sup 85}Kr, {sup 14}C) were largely removed during production testing in 1969 and 1970 and are no longer present in appreciable amounts. Substantial tritium remained because it is part of the water molecule, which is present in both the gas and liquid (aqueous) phases. The objectives of this work are to calculate the nature and extent of tritium contamination in the subsurface from the Rulison test from the time of the test to present day (2007), and to evaluate tritium migration under natural-gas production conditions to a hypothetical gas production well in the most vulnerable location outside the DOE drilling restriction. The natural-gas production scenario involves a hypothetical production well located 258 m horizontally away from the detonation point, outside the edge of the current drilling exclusion area. The production interval in the hypothetical well is at the same elevation as the nuclear chimney created by the detonation, in order to evaluate the location most vulnerable to tritium migration.

  5. HIGH RESOLUTION PREDICTION OF GAS INJECTION PROCESS PERFORMANCE FOR HETEROGENEOUS RESERVOIRS

    SciTech Connect (OSTI)

    Franklin M. Orr, Jr.

    2004-05-01

    This final technical report describes and summarizes results of a research effort to investigate physical mechanisms that control the performance of gas injection processes in heterogeneous reservoirs and to represent those physical effects in an efficient way in simulations of gas injection processes. The research effort included four main lines of research: (1) Efficient compositional streamline methods for 3D flow; (2) Analytical methods for one-dimensional displacements; (3) Physics of multiphase flow; and (4) Limitations of streamline methods. In the first area, results are reported that show how the streamline simulation approach can be applied to simulation of gas injection processes that include significant effects of transfer of components between phases. In the second area, the one-dimensional theory of multicomponent gas injection processes is extended to include the effects of volume change as components change phase. In addition an automatic algorithm for solving such problems is described. In the third area, results on an extensive experimental investigation of three-phase flow are reported. The experimental results demonstrate the impact on displacement performance of the low interfacial tensions between the gas and oil phases that can arise in multicontact miscible or near-miscible displacement processes. In the fourth area, the limitations of the streamline approach were explored. Results of an experimental investigation of the scaling of the interplay of viscous, capillary, and gravity forces are described. In addition results of a computational investigation of the limitations of the streamline approach are reported. The results presented in this report establish that it is possible to use the compositional streamline approach in many reservoir settings to predict performance of gas injection processes. When that approach can be used, it requires substantially less (often orders of magnitude) computation time than conventional finite difference compositional simulation.

  6. Fracture Modeling and Flow Behavior in Shale Gas Reservoirs Using Discrete Fracture Networks 

    E-Print Network [OSTI]

    Ogbechie, Joachim Nwabunwanne

    2012-02-14

    Fluid flow process in fractured reservoirs is controlled primarily by the connectivity of fractures. The presence of fractures in these reservoirs significantly affects the mechanism of fluid flow. They have led to problems in the reservoir which...

  7. Analysis of the Development of Messoyakha Gas Field: A Commercial Gas Hydrate Reservoir 

    E-Print Network [OSTI]

    Omelchenko, Roman 1987-

    2012-12-11

    Natural gas is an important energy source that contributes up to 25% of the total US energy reserves (DOE 2011). An increase in natural gas demand spurs further development of unconventional resources, including methane hydrate (Rajnauth 2012...

  8. Numerical Modeling of Fractured Shale-Gas and Tight-Gas Reservoirs Using Unstructured Grids 

    E-Print Network [OSTI]

    Olorode, Olufemi Morounfopefoluwa

    2012-02-14

    Various models featuring horizontal wells with multiple induced fractures have been proposed to characterize flow behavior over time in tight gas and shale gas systems. Currently, there is little consensus regarding the effects of non...

  9. Study of Multi-scale Transport Phenomena in Tight Gas and Shale Gas Reservoir Systems 

    E-Print Network [OSTI]

    Freeman, Craig Matthew

    2013-11-25

    . These challenges have impeded efficient economic development of shale resources. New fundamental insights and tools are needed to improve the state of shale gas development. Few attempts have been made to model the compositional behavior of fluids in shale gas...

  10. An evaluation of the deep reservoir conditions of the Bacon-Manito geothermal field, Philippines using well gas chemistry

    SciTech Connect (OSTI)

    D'Amore, Franco; Maniquis-Buenviaje, Marinela; Solis, Ramonito P.

    1993-01-28

    Gas chemistry from 28 wells complement water chemistry and physical data in developing a reservoir model for the Bacon-Manito geothermal project (BMGP), Philippines. Reservoir temperature, THSH, and steam fraction, y, are calculated or extrapolated from the grid defined by the Fischer-Tropsch (FT) and H2-H2S (HSH) gas equilibria reactions. A correction is made for H2 that is lost due to preferential partitioning into the vapor phase and the reequilibration of H2S after steam loss.

  11. The effect of high-pressure injection of gas on the reservoir volume factor of a crude oil 

    E-Print Network [OSTI]

    Honeycutt, Baxter Bewitt

    1957-01-01

    THE EFFECT OF HIGH-PRESSURE INJECTION OF GAS ON THE RESERVOIR VOLUME FACTOR OF A CRUDE OIL A Thesis By+ BAXTER DS'kONEYCUTT o Submitted to the Graduate School of the Agricultural and Mechanical College of Texas in partial fulfillment... of the requirements for the degree of MASTER OF SCIENCE August, i957 Major Subject: Petroleum Engineering THE EFFECT OF HIGH-PRESSURE INJECTION OF GAS ON THE RESERVOIR VOLUME FACTOR OF A CRUDE OIL A Thesis By BAXTER D. HONEYCUTT Appro d as to style...

  12. Application of coiled-tubing-drilling technology on a deep underpressured gas reservoir

    SciTech Connect (OSTI)

    1997-06-01

    The Upper-Mississippian Elkton formation is a dolomitized shallow-water carbonate consisting of dense limestones and porous dolomites. The Elkton was deposited in an open-shelf environment as crinoid grainstones, coral packstones, and lime muds. Deposition of impermeable shales and siltstones of the Lower Cretaceous created the lateral and updip seals. Reservoir thickness can be up to 20 m, with porosities reaching 20% and averaging 10%. The reservoir gas contains approximately 0.5% hydrogen sulfide. Well 11-18 was to be completed in the Harmatten Elkton pool. The pool went on production in 1967 at an initial pressure of 23,500 kPa. At the current pressure of 16,800 kPa, the remaining reserves are underpressured at 6.5 kPa/m, and underbalanced horizontal drilling was selected as the most suitable technique for exploiting remaining reserves. Coiled-tubing (CT) technology was selected to ensure continuous underbalanced conditions and maintain proper well control while drilling. The paper describes the equipment, CT drilling summary, and drilling issues.

  13. Invasion Correction of Acoustic Logs in a Gas Reservoir Shihong Chi*, Jianghui Wu, and Carlos Torres-Verdin, The University of Texas at Austin

    E-Print Network [OSTI]

    Torres-Verdín, Carlos

    Invasion Correction of Acoustic Logs in a Gas Reservoir Shihong Chi*, Jianghui Wu, and Carlos-wave velocities in the near-wellbore region. This study focuses on two wells in a gas reservoir. The radial saturation distribution of mud filtrate and connate formation fluids is first obtained by simulating the mud

  14. Carbon dioxide and helium emissions from a reservoir of magmatic gas beneath Mammoth Mountain, California

    SciTech Connect (OSTI)

    Sorey, M.L.; Evans, W.C. [U.S. Geological Survey, Menlo Park, California (United States)] Kennedy, B.M. [Lawrence Berkeley National Laboratory, Berkeley, California (United States)] Farrar, C.D. [U.S. Geological Survey, Carnelian Bay, California (United States)] Hainsworth, L.J. [Chemistry Department, Emory and Henry College, Emory, Virginia (United States)] Hausback, B. [Geology Department, California State University, Sacramento

    1998-07-01

    Carbon dioxide and helium with isotopic compositions indicative of a magmatic source ({delta}thinsp{sup 13}C={minus}4.5 to {minus}5{per_thousand}, {sup 3}He/{sup 4}He=4.5 to 6.7 R{sub A}) are discharging at anomalous rates from Mammoth Mountain, on the southwestern rim of the Long Valley caldera in eastern California. The gas is released mainly as diffuse emissions from normal-temperature soils, but some gas issues from steam vents or leaves the mountain dissolved in cold groundwater. The rate of gas discharge increased significantly in 1989 following a 6-month period of persistent earthquake swarms and associated strain and ground deformation that has been attributed to dike emplacement beneath the mountain. An increase in the magmatic component of helium discharging in a steam vent on the north side of Mammoth Mountain, which also began in 1989, has persisted until the present time. Anomalous CO{sub 2} discharge from soils first occurred during the winter of 1990 and was followed by observations of several areas of tree kill and/or heavier than normal needlecast the following summer. Subsequent measurements have confirmed that the tree kills arc associated with CO{sub 2} concentrations of 30{endash}90{percent} in soil gas and gas flow rates of up to 31,000 gthinspm{sup {minus}2}thinspd{sup {minus}1} at the soil surface. Each of the tree-kill areas and one area of CO{sub 2} discharge above tree line occurs in close proximity to one or more normal faults, which may provide conduits for gas flow from depth. We estimate that the total diffuse CO{sub 2} flux from the mountain is approximately 520 t/d, and that 30{endash}50 t/d of CO{sub 2} are dissolved in cold groundwater flowing off the flanks of the mountain. Isotopic and chemical analyses of soil and fumarolic gas demonstrate a remarkable homogeneity in composition, suggesting that the CO{sub 2} and associated helium and excess nitrogen may be derived from a common gas reservoir whose source is associated with some combination of magmatic degassing and thermal metamorphism of metasedimentary rocks. Furthermore, N{sub 2}/Ar ratios and nitrogen isotopic values indicate that the Mammoth Mountain gases are derived from sources separate from those that supply gas to the hydrothermal system within the Long Valley caldera. Various data suggest that the Mammoth Mountain gas reservoir is a large, low-temperature cap over an isolated hydrothermal system, that it predates the 1989 intrusion, and that it could remain a source of gas discharge for some time. {copyright} 1998 American Geophysical Union

  15. Layered Pseudo-Steady-State Models for tight commingled gas reservoirs 

    E-Print Network [OSTI]

    El-Banbi, Ahmed

    1995-01-01

    Analysis of commingled reservoirs from limited data can be a challenge to most conventional reservoir engineering tools. The purpose of this research is to find an effective and easy technique that can be used to estimate ...

  16. Reservoir characterization in an underground gas storage field using joint inversion of flow and geodetic data

    E-Print Network [OSTI]

    Bottazzi, F.

    Characterization of reservoir properties like porosity and permeability in reservoir models typically relies on history matching of production data, well pressure data, and possibly other fluid-dynamical data. Calibrated ...

  17. Control of water coning in gas reservoirs by injecting gas into the aquifer 

    E-Print Network [OSTI]

    Haugen, Sigurd Arild

    1980-01-01

    implicit model. The model is thoroughly tested for both coning and other problems, including both gas and oil. It was very stable, allowing a maximum saturation change per timestep as high as 10 per cent. The condition simulated was a well in the center... saturation chanqes are expected to be large, the porosity was set to 100 percent in the gas zone, and 1, 000, 300, and 100 percent in the cells outward from the wellbore in the water zone. This can be seen in Figure 3. These high porosi- ty values were...

  18. Altering Wettability in Gas Condensate Sandstone Reservoirs for Gas Mobillity Improvement 

    E-Print Network [OSTI]

    Fernandez Martinez, Ruth Gabriela

    2012-07-16

    w 7). well. The li p to 50% i of feet in ra stration bel nce increase mobility in incremental r ). here condens quid saturati n some ca dius, but ev ow we can s. Condens this area adial distanc 2 ate on ses en see ate... (Anderson, W.G. 1987), P? ? P???P?,?????????????...?(1) where ?? is capillary pressure, ??? represents the pressure of the gas phase and ?? represents the pressure of the liquid phase in gas-condensate systems. As the condensate bank is formed...

  19. Performance analysis of compositional and modified black-oil models for rich gas condensate reservoirs with vertical and horizontal wells 

    E-Print Network [OSTI]

    Izgec, Bulent

    2004-09-30

    various production and injection scenarios for a rich gas condensate reservoir. The software used to perform the compositional and MBO runs were Eclipse 300 and Eclipse 100 versions 2002A. The effects of black-oil PVT table generation methods, uniform...

  20. DOE THREE-DIMENSIONAL STRUCTURE AND PHYSICAL PROPERTIES OF A METHANE HYDRATE DEPOSIT AND GAS RESERVOIR, BLAKE RIDGE

    SciTech Connect (OSTI)

    W. Steven Holbrook

    2004-11-11

    This report contains a summary of work conducted and results produced under the auspices of award DE-FC26-00NT40921, ''DOE Three-Dimensional Structure and Physical Properties of a Methane Hydrate Deposit and Gas Reservoir, Blake Ridge.'' This award supported acquisition, processing, and interpretation of two- and three-dimensional seismic reflection data over a large methane hydrate reservoir on the Blake Ridge, offshore South Carolina. The work supported by this project has led to important new conclusions regarding (1) the use of seismic reflection data to directly detect methane hydrate, (2) the migration and possible escape of free gas through the hydrate stability zone, and (3) the mechanical controls on the maximum thickness of the free gas zone and gas escape.

  1. Pore-scale mechanisms of gas flow in tight sand reservoirs

    SciTech Connect (OSTI)

    Silin, D.; Kneafsey, T.J.; Ajo-Franklin, J.B.; Nico, P.

    2010-11-30

    Tight gas sands are unconventional hydrocarbon energy resource storing large volume of natural gas. Microscopy and 3D imaging of reservoir samples at different scales and resolutions provide insights into the coaredo not significantly smaller in size than conventional sandstones, the extremely dense grain packing makes the pore space tortuous, and the porosity is small. In some cases the inter-granular void space is presented by micron-scale slits, whose geometry requires imaging at submicron resolutions. Maximal Inscribed Spheres computations simulate different scenarios of capillary-equilibrium two-phase fluid displacement. For tight sands, the simulations predict an unusually low wetting fluid saturation threshold, at which the non-wetting phase becomes disconnected. Flow simulations in combination with Maximal Inscribed Spheres computations evaluate relative permeability curves. The computations show that at the threshold saturation, when the nonwetting fluid becomes disconnected, the flow of both fluids is practically blocked. The nonwetting phase is immobile due to the disconnectedness, while the permeability to the wetting phase remains essentially equal to zero due to the pore space geometry. This observation explains the Permeability Jail, which was defined earlier by others. The gas is trapped by capillarity, and the brine is immobile due to the dynamic effects. At the same time, in drainage, simulations predict that the mobility of at least one of the fluids is greater than zero at all saturations. A pore-scale model of gas condensate dropout predicts the rate to be proportional to the scalar product of the fluid velocity and pressure gradient. The narrowest constriction in the flow path is subject to the highest rate of condensation. The pore-scale model naturally upscales to the Panfilov's Darcy-scale model, which implies that the condensate dropout rate is proportional to the pressure gradient squared. Pressure gradient is the greatest near the matrix-fracture interface. The distinctive two-phase flow properties of tight sand imply that a small amount of gas condensate can seriously affect the recovery rate by blocking gas flow. Dry gas injection, pressure maintenance, or heating can help to preserve the mobility of gas phase. A small amount of water can increase the mobility of gas condensate.

  2. Investigation of gas hydrate-bearing sandstone reservoirs at the "Mount Elbert" stratigraphic test well, Milne Point, Alaska

    SciTech Connect (OSTI)

    Boswell, R.M.; Hunter, R.; Collett, T.; Digert, S. Inc., Anchorage, AK); Hancock, S.; Weeks, M. Inc., Anchorage, AK); Mt. Elbert Science Team

    2008-01-01

    In February 2007, the U.S. Department of Energy, BP Exploration (Alaska), Inc., and the U.S. Geological Survey conducted an extensive data collection effort at the "Mount Elbert #1" gas hydrates stratigraphic test well on the Alaska North Slope (ANS). The 22-day field program acquired significant gas hydrate-bearing reservoir data, including a full suite of open-hole well logs, over 500 feet of continuous core, and open-hole formation pressure response tests. Hole conditions, and therefore log data quality, were excellent due largely to the use of chilled oil-based drilling fluids. The logging program confirmed the existence of approximately 30 m of gashydrate saturated, fine-grained sand reservoir. Gas hydrate saturations were observed to range from 60% to 75% largely as a function of reservoir quality. Continuous wire-line coring operations (the first conducted on the ANS) achieved 85% recovery through 153 meters of section, providing more than 250 subsamples for analysis. The "Mount Elbert" data collection program culminated with open-hole tests of reservoir flow and pressure responses, as well as gas and water sample collection, using Schlumberger's Modular Formation Dynamics Tester (MDT) wireline tool. Four such tests, ranging from six to twelve hours duration, were conducted. This field program demonstrated the ability to safely and efficiently conduct a research-level openhole data acquisition program in shallow, sub-permafrost sediments. The program also demonstrated the soundness of the program's pre-drill gas hydrate characterization methods and increased confidence in gas hydrate resource assessment methodologies for the ANS.

  3. Using ArcGIS to extrapolate greenhouse gas emissions on the Pengxi River, a tributary of the Three Gorges Reservoir in China

    E-Print Network [OSTI]

    Yasarer, Lindsey

    2014-11-19

    Using ArcGIS to extrapolate greenhouse gas emissions on the Pengxi River, a tributary of the Three Gorges Reservoir in China Lindsey MW Yasarer, PhD Candidate, University of Kansas Dr. Zhe Li, Associate Professor, Chongqing University Dr.... Belinda Sturm, Associate Professor, University of Kansas RESERVOIR GREENHOUSE GAS EMISSIONS (Image from FURNAS www.dsr.inpe.br) HOW TO SCALE UP GHG EMISSIONS? PROJECT OBJECTIVE: Estimate overall greenhouse gas emissions from the Pengxi River Backwater...

  4. Joule-Thomson Cooling Due to CO2 Injection into Natural Gas Reservoirs

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2006-01-01

    cushion gas for natural gas storage, Energy & Fuels, 17(1),cushion gas for natural gas storage (Oldenburg, 2003). For

  5. Secondary natural gas recovery: Targeted applications for infield reserve growth in midcontinent reservoirs, Boonsville Field, Fort Worth Basin, Texas. Topical report, May 1993--June 1995

    SciTech Connect (OSTI)

    Hardage, B.A.; Carr, D.L.; Finley, R.J.; Tyler, N.; Lancaster, D.E.; Elphick, R.Y.; Ballard, J.R.

    1995-07-01

    The objectives of this project are to define undrained or incompletely drained reservoir compartments controlled primarily by depositional heterogeneity in a low-accommodation, cratonic Midcontinent depositional setting, and, afterwards, to develop and transfer to producers strategies for infield reserve growth of natural gas. Integrated geologic, geophysical, reservoir engineering, and petrophysical evaluations are described in complex difficult-to-characterize fluvial and deltaic reservoirs in Boonsville (Bend Conglomerate Gas) field, a large, mature gas field located in the Fort Worth Basin of North Texas. The purpose of this project is to demonstrate approaches to overcoming the reservoir complexity, targeting the gas resource, and doing so using state-of-the-art technologies being applied by a large cross section of Midcontinent operators.

  6. Implementation of the Ensemble Kalman Filter in the Characterization of Hydraulic Fractures in Shale Gas Reservoirs by Integrating Downhole Temperature Sensing Technology 

    E-Print Network [OSTI]

    Moreno, Jose A

    2014-08-12

    Multi-stage hydraulic fracturing in horizontal wells has demonstrated successful results for developing unconventional low-permeability oil and gas reservoirs. Despite being vastly implemented by different operators across North America, hydraulic...

  7. Pore-scale mechanisms of gas flow in tight sand reservoirs

    E-Print Network [OSTI]

    Silin, D.

    2011-01-01

    production increased. Unconventional gas resources accountedwellbores. ” Unconventional gas resources traditionallysand is an unconventional natural gas resource. According to

  8. A combined saline formation and gas reservoir CO2 injection pilot in Northern California

    E-Print Network [OSTI]

    Trautz, Robert; Myer, Larry; Benson, Sally; Oldenburg, Curt; Daley, Thomas; Seeman, Ed

    2006-01-01

    cushion gas for natural gas storage. Energy & Fuels, 2003; [demonstrate CO 2 Storage with Enhanced Gas Recovery (CSEGR).formations and storage/enhanced recovery projects in gas

  9. Petrophysical Analysis and Geographic Information System for San Juan Basin Tight Gas Reservoirs

    SciTech Connect (OSTI)

    Martha Cather; Robert Lee; Robert Balch; Tom Engler; Roger Ruan; Shaojie Ma

    2008-10-01

    The primary goal of this project is to increase the availability and ease of access to critical data on the Mesaverde and Dakota tight gas reservoirs of the San Juan Basin. Secondary goals include tuning well log interpretations through integration of core, water chemistry and production analysis data to help identify bypassed pay zones; increased knowledge of permeability ratios and how they affect well drainage and thus infill drilling plans; improved time-depth correlations through regional mapping of sonic logs; and improved understanding of the variability of formation waters within the basin through spatial analysis of water chemistry data. The project will collect, integrate, and analyze a variety of petrophysical and well data concerning the Mesaverde and Dakota reservoirs of the San Juan Basin, with particular emphasis on data available in the areas defined as tight gas areas for purpose of FERC. A relational, geo-referenced database (a geographic information system, or GIS) will be created to archive this data. The information will be analyzed using neural networks, kriging, and other statistical interpolation/extrapolation techniques to fine-tune regional well log interpretations, improve pay zone recognition from old logs or cased-hole logs, determine permeability ratios, and also to analyze water chemistries and compatibilities within the study area. This single-phase project will be accomplished through four major tasks: Data Collection, Data Integration, Data Analysis, and User Interface Design. Data will be extracted from existing databases as well as paper records, then cleaned and integrated into a single GIS database. Once the data warehouse is built, several methods of data analysis will be used both to improve pay zone recognition in single wells, and to extrapolate a variety of petrophysical properties on a regional basis. A user interface will provide tools to make the data and results of the study accessible and useful. The final deliverable for this project will be a web-based GIS providing data, interpretations, and user tools that will be accessible to anyone with Internet access. During this project, the following work has been performed: (1) Assimilation of most special core analysis data into a GIS database; (2) Inventorying of additional data, such as log images or LAS files that may exist for this area; (3) Analysis of geographic distribution of that data to pinpoint regional gaps in coverage; (4) Assessment of the data within both public and proprietary data sets to begin tuning of regional well logging analyses and improve payzone recognition; (5) Development of an integrated web and GIS interface for all the information collected in this effort, including data from northwest New Mexico; (6) Acquisition and digitization of logs to create LAS files for a subset of the wells in the special core analysis data set; and (7) Petrophysical analysis of the final set of well logs.

  10. HIGH RESOLUTION PREDICTION OF GAS INJECTION PROCESS PERFORMANCE FOR HETEROGENEOUS RESERVOIRS

    SciTech Connect (OSTI)

    Franklin M. Orr, Jr.

    2003-09-30

    This report outlines progress in the first quarter of the extension of the DOE project ''High Resolution Prediction of Gas Injection Process Performance for Heterogeneous Reservoirs''. This report presents experimental results that demonstrate combined scaling effects of viscous, capillary, and gravity crossflow mechanisms that apply to the situations in which streamline models are used. We designed and ran a series of experiments to investigate combined effects of capillary, viscous, and gravity forces on displacement efficiency in layered systems. Analog liquids (isooctane, isopropanol, and water) were employed to control scaling parameters by changing interfacial tension (IFT), flow rate, and density difference. The porous medium was a two-dimensional (2-D) 2-layered glass bead model with a permeability ratio of about 1:4. In order to analyze the combined effect of only capillary and viscous forces, gravity effects were eliminated by changing the orientation of the glass bead model. We employed a commercial simulator, Eclipse100 to calculate displacement behavior for comparison with the experimental data. Experimental results with minimized gravity effects show that the IFT and flow rate determine how capillary and viscous forces affect behavior of displacement. The limiting behavior for scaling groups for two-phase displacement was verified by experimental results. Analysis of the 2-D images indicates that displacements having a capillary-viscous equilibrium give the best sweep efficiency. Experimental results with gravity effects, but with low IFT fluid systems show that slow displacements produce larger area affected by crossflow. This, in turn, enhances sweep efficiency. The simulation results represent the experimental data well, except for the situations where capillary forces dominate the displacement.

  11. Modeling Performance of Horizontal Wells with Multiple Fractures in Tight Gas Reservoirs 

    E-Print Network [OSTI]

    Dong, Guangwei

    2011-02-22

    Multiple transverse fracturing along a horizontal well is a relatively new technology that is designed to increase well productivity by increasing the contact between the reservoir and the wellbore. For multiple transverse fractures, the performance...

  12. Stochastic Modeling of a Fracture Network in a Hydraulically Fractured Shale-Gas Reservoir 

    E-Print Network [OSTI]

    Mhiri, Adnene

    2014-08-10

    The fundamental behavior of fluid production from shale/ultra-low permeability reservoirs that are produced under a constant wellbore pressure remains difficult to quantify, which is believed to be (at least in part) due to the complexity...

  13. Preliminary formation analysis for compressed air energy storage in depleted natural gas reservoirs : a study for the DOE Energy Storage Systems Program.

    SciTech Connect (OSTI)

    Gardner, William Payton

    2013-06-01

    The purpose of this study is to develop an engineering and operational understanding of CAES performance for a depleted natural gas reservoir by evaluation of relative permeability effects of air, water and natural gas in depleted natural gas reservoirs as a reservoir is initially depleted, an air bubble is created, and as air is initially cycled. The composition of produced gases will be evaluated as the three phase flow of methane, nitrogen and brine are modeled. The effects of a methane gas phase on the relative permeability of air in a formation are investigated and the composition of the produced fluid, which consists primarily of the amount of natural gas in the produced air are determined. Simulations of compressed air energy storage (CAES) in depleted natural gas reservoirs were carried out to assess the effect of formation permeability on the design of a simple CAES system. The injection of N2 (as a proxy to air), and the extraction of the resulting gas mixture in a depleted natural gas reservoir were modeled using the TOUGH2 reservoir simulator with the EOS7c equation of state. The optimal borehole spacing was determined as a function of the formation scale intrinsic permeability. Natural gas reservoir results are similar to those for an aquifer. Borehole spacing is dependent upon the intrinsic permeability of the formation. Higher permeability allows increased injection and extraction rates which is equivalent to more power per borehole for a given screen length. The number of boreholes per 100 MW for a given intrinsic permeability in a depleted natural gas reservoir is essentially identical to that determined for a simple aquifer of identical properties. During bubble formation methane is displaced and a sharp N2methane boundary is formed with an almost pure N2 gas phase in the bubble near the borehole. During cycling mixing of methane and air occurs along the boundary as the air bubble boundary moves. The extracted gas mixture changes as a function of time and proximity of the bubble boundary to the well. For all simulations reported here, with a formation radius above 50 m the maximum methane composition in the produced gas phase was less than 0.5%. This report provides an initial investigation of CAES in a depleted natural gas reservoir, and the results will provide useful guidance in CAES system investigation and design in the future.

  14. Integrated seismic study of naturally fractured tight gas reservoirs. Technical progress report, January 1, 1994--March 31, 1994

    SciTech Connect (OSTI)

    Mavko, G.; Nur, A.

    1994-04-29

    The study area is located at the southern end of the Powder River Basin in Converse County in east-central Wyoming. It is a low permeability fractured site, with both gas and oil present. Reservoirs are highly compartmentalized due to the low permeabilities, and fractures provide the only practical drainage paths for production. The two formations of interest are: The Niobrara, a fractured shale and limey shale to chalk, which is a reservoir rock, but also its own source rock; and the Frontier, a tight sandstone lying directly below the Niobrara, brought into contact with it by an unconformity. This was the tenth quarter of the contract. During this quarter the investigators (1) continued processing the seismic data, and (2) continued modeling some of the P-wave amplitude anomalies that we see in the data.

  15. Pore-scale mechanisms of gas flow in tight sand reservoirs

    E-Print Network [OSTI]

    Silin, D.

    2011-01-01

    adjacent fractures. Natural gas composition consists mostlyNatural gas is called wet or dry depending on how large is the lique?able portion of gas composition.

  16. Pore-scale mechanisms of gas flow in tight sand reservoirs

    E-Print Network [OSTI]

    Silin, D.

    2011-01-01

    include tight gas sands, gas shales, and coal-bed methane.Figure 3. Although the gas-shale production grows at a

  17. CO2 utilization and storage in shale gas reservoirs: Experimental results and economic impacts

    SciTech Connect (OSTI)

    Schaef, Herbert T.; Davidson, Casie L.; Owen, Antionette Toni; Miller, Quin R. S.; Loring, John S.; Thompson, Christopher J.; Bacon, Diana H.; Glezakou, Vassiliki Alexandra; McGrail, B. Peter

    2014-12-31

    Natural gas is considered a cleaner and lower-emission fuel than coal, and its high abundance from advanced drilling techniques has positioned natural gas as a major alternative energy source for the U.S. However, each ton of CO2 emitted from any type of fossil fuel combustion will continue to increase global atmospheric concentrations. One unique approach to reducing anthropogenic CO2 emissions involves coupling CO2 based enhanced gas recovery (EGR) operations in depleted shale gas reservoirs with long-term CO2 storage operations. In this paper, we report unique findings about the interactions between important shale minerals and sorbing gases (CH4 and CO2) and associated economic consequences. Where enhanced condensation of CO2 followed by desorption on clay surface is observed under supercritical conditions, a linear sorption profile emerges for CH4. Volumetric changes to montmorillonites occur during exposure to CO2. Theory-based simulations identify interactions with interlayer cations as energetically favorable for CO2 intercalation. Thus, experimental evidence suggests CH4 does not occupy the interlayer and has only the propensity for surface adsorption. Mixed CH4:CO2 gas systems, where CH4 concentrations prevail, indicate preferential CO2 sorption as determined by in situ infrared spectroscopy and X-ray diffraction techniques. Collectively, these laboratory studies combined with a cost-based economic analysis provide a basis for identifying favorable CO2-EOR opportunities in previously fractured shale gas reservoirs approaching final stages of primary gas production. Moreover, utilization of site-specific laboratory measurements in reservoir simulators provides insight into optimum injection strategies for maximizing CH4/CO2 exchange rates to obtain peak natural gas production.

  18. Factors that affect fracture fluid clean-up and pressure buildup test results in tight gas reservoirs 

    E-Print Network [OSTI]

    Montgomery, Kevin Todd

    1990-01-01

    FACTORS THAT AFFECT FRACTURE FLUID CLEAN-UP AND PRESSURE BUILDUP TEST RESULTS IN TIGHT GAS RESERVOIRS A Thesis KEVIN TODD MONTGOMERY Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements... of Clean-up of the Invaded Zone Simulation of the Buildup Tests FACTORS AFFECTING FRACTURE FLUID CLEAN-UP Page v 1v 15 17 47 Effect of Dimensionless Fracture Conductivity on Clean-up . . 47 Effect of Fracture Length on Clean-up Effect...

  19. UONPR No. 1, Elk Hills, 26R Reservoir, Elk Hills oil and gas field, Kern County, California: Management Review: Surface operations and measurements of production and injection volumes

    SciTech Connect (OSTI)

    Not Available

    1987-01-01

    Evans, Carey and Crozier was given the task to conduct a Management Review of the Surface Operations of the 26R Reservoir in UONPR No. 1, Elk Hills field, Kern County, California. The MER strategy for this reservoir is to maintain pressure, and toward this end, gas injection volumes are scheduled to amount to 110% of calculated withdrawals. In spite of this, however, reservoir pressure continues to decline. The purpose of this study was, therefore, to determine if, and to what extent, field operating practices and accounting procedures may be contributing to this dilemma and to make appropriate recommendations pertaining to correcting any deficiencies which may have been found.

  20. Geological controls on gas accumulation in a unique Zechstein carbonate reservoir

    E-Print Network [OSTI]

    anhydrite and halite (salt)), that are well known both for their mobility (halokenesis) and ability to trap hydrocarbons as an effective reservoir seal. Deep in the palaeo-basin centre, salts (anhydrite and halite to two stages of tectonic inversion (re-activation in compression of the initially extensional faults

  1. Dry Gas Zone, Elk Hills field, Kern County, California: General reservoir study: Engineering text and exhibits: (Final report)

    SciTech Connect (OSTI)

    Not Available

    1988-08-01

    The Dry Gas Zone in the Elk Hills field is comprised of fourteen separate productive horizons deposited in the MYA Group of the San Joaquin Formation of Pliocene Age. Eighty-six separate Reservoir Units have been identified within the interval over an area roughly ten miles long and four miles wide. One basal Tulare sand, the Tulare B, was also included in the geologic study. Five earlier studies have been made of the Dry Gas Zone; each is referenced in the Appendix of this report. Most of these studies were geologic in nature, and none provided in-depth reservoir analyses. This report is made up of ten (10) separate volumes which include: engineering text and exhibits (white dot); engineering data (black dot); geologic text and tables (green dot); structure and isochore maps (light blue dot); structural cross sections (dark blue dot); stratigraphic cross sections (brown dot); geologic data sheets -book 1 (yellow dot); geologic data sheets - book 2 (orange dot); geologic data sheets - book 3 (red dot); and geologic data sheets - book 4 (pink or coral dot). Basic production, injection, pressure, and other assorted technical data were provided by the US Department of Energy engineering staff at Elk Hills. These data were accepted as furnished with no attempt being made at independent verification.

  2. Depositional environment and reservoir morphology of the Upper Wilcox sandstones, Katy gas field, Waller County, Texas 

    E-Print Network [OSTI]

    DePaul, Gilbert John

    1979-01-01

    and structural characteristics of the field. The Upper Wilcox is divided into the following units, in ascending order, "First Lower Massive" sandstones and "D", "C", "B", "A", "Second Wilcox" and "First Wilcox" interbedded sandstones and shales. The reservoir... and are generally abruptly overla1n by sandstones with sharp or erosional bases. The sandstones change laterally to thin sandstones interlaminated with thick shales. The thick sandstones are submarine, constructional- channel deposits with associated thin...

  3. Numerical Simulation and Multiple Realizations for Sensitivity Study of Shale Gas Reservoir

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    SPE 141058 Numerical Simulation and Multiple Realizations for Sensitivity Study of Shale Gas. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Shale gas in the United States the largest conventional gas accumulations in the world. Shale gas success is directly the result

  4. Dry Gas Zone, Elk Hills Field, Kern County, California: General reservoir study: Geologic text and tables: Final report

    SciTech Connect (OSTI)

    Not Available

    1988-06-29

    The Dry Gas Zone was defined by US Naval Petroleum Reserve No. 1 Engineering Committee (1957) as ''/hor ellipsis/all sands bearing dry gas above the top of the Lower Scalez marker bed. The term is used to include the stratigraphic interval between the Scalez Sand Zone and the Tulare Formation - the Mya Sand Zone. The reservoirs in this upper zone are thin, lenticular, loosely cemented sandstones with relatively high permeabilities.'' Other than the limited Tulare production in the western part of the field, the Dry Gas Zone is the shallowest productive zone in the Elk Hills Reserve and is not included in the Shallow Oil Zone. It is Pliocene in age and makes up approximately eighty percent of the San Joaquin Formation as is summarized in Exhibit TL-1. The lithologic character of the zone is one of interbedded shales and siltstones with intermittent beds of various thickness sands. The stratigraphic thickness of the Dry Gas Zone ranges from 950 to 1150 feet with a general thickening along the flanks and thinning over the crests of the anticlines. The productive part of the Dry Gas Zone covers portions of 30 sections in an area roughly 10 miles long by 4 miles wide. 4 refs.

  5. Evaluating reservoir production strategies in miscible and immiscible gas-injection projects 

    E-Print Network [OSTI]

    Farzad, Iman

    2004-11-15

    Miscible gas injection processes could be among the most widely used enhanced oil recovery processes. Successful design and implementation of a miscible gas injection project depends upon the accurate determination of the minimum miscibility...

  6. Modeling of performance behavior in gas condensate reservoirs using a variable mobility concept 

    E-Print Network [OSTI]

    Wilson, Benton Wade

    2004-09-30

    of the new model (t (? p /? tD D D) for- mulation (Eq. 1.6)). Solution is plotted versus the inverse of the modified Boltzmann transform variable 2DDD r 10 In Fig. 1.4 we present the radial derivative function pDdr(? D) function plotted versus... the modified Boltzmann transform variable The p2 DDD t Ddr(? D) formulation represents the change in pressure drop with respect to radius as we move out into the reservoir ? clearly there are separate factors at issue ? the behavior of the |rD(? pD/? r...

  7. Integrated seismic study of naturally fractured tight gas reservoirs. Technical progress report, October 1, 1992--December 31, 1992

    SciTech Connect (OSTI)

    Nur, A.

    1993-01-21

    This was the fifth quarter of the contract. During this quarter we (1) got approval for the NEPA requirements related to the field work, (2) placed the subcontract for the field data acquisition, (3) completed the field work, and (4) began processing the seismic data. As already reported, the field data acquisition was at Acomo`s Powder River Basin site in southeast Wyoming. This is a low permeability fractured site, with both gas and oil present. The reservoir is highly compartmentalized, due to the low permeability, with the fractures providing the only practical drainage paths for production. The two formations of interest are: The Niobrara: a fractured shale and limey shale to chalk, which is a reservoir rock, but also its own source rock. The Frontier: a tight sandstone lying directly below the Niobrara, brought into contact with it by an unconformity. The fractures are thought to lie in a roughly northwest-southeast trend, along the strike of a flexure, which forms one of the boundaries of the basin.

  8. Integrated seismic study of naturally fractured tight gas reservoirs. Technical progress report, January 1, 1993--March 31, 1993

    SciTech Connect (OSTI)

    Mavko, G.; Nur, A.

    1993-04-26

    During this quarter we (1) received the last of the field tapes and survey information for the seismic field data acquisition which was finished at the very end of the previous quarter, (2) began the large task of processing the seismic data, (3) collected well logs and other informination to aid in the interpretation, and (4) initiated some seismic modeling studies. As already reported, the field data acquisition was at Amoco`s Powder River Basin site in southeast Wyoming. This is a low permeability fractured site, with both gas and oil present. The reservoir is highly compartmentalized, due to the low permeability, with the fractures providing the only practical drainage paths for production. The two formations of interest are: The Niobrara: a fractured shale and limey shale to chalk, which is a reservoir rock, but also its own source rock. The Frontier: a tight sandstone lying directly below the Niobrara, brought into contact with it by an unconformity. The fractures are thought to lie in a roughly northwest-southeast trend, along the strike of a flexure, which forms one of the boundaries of the basin.

  9. Integrated seismic study of naturally fractured tight gas reservoirs. Technical progress report, April 1, 1993--June 31, 1993

    SciTech Connect (OSTI)

    Mavko, G.; Nur, A.

    1993-07-26

    This was the seventh quarter of the contract. During this quarter we (1) continued the large task of processing the seismic data, (2) collected additional geological information to aid in the interpretation, (3) tied the well log data to the seismic via generation of synthetic seismograms, (4) began integrating regional structural information and fracture trends with our observations of structure in the study area, (5) began constructing a velocity model for time-to-depth conversion and subsequent AVO and raytrace modeling experiments, and (6) completed formulation of some theoretical tools for relating fracture density to observed elastic anisotropy. The study area is located at the southern end of the Powder River Basin in Converse County in east-central Wyoming. It is a low permeability fractured site, with both gas and oil present. Reservoirs are highly compartmentalized due to the low permeabilities, and fractures provide the only practical drainage paths for production. The two formations of interest are: The Niobrara: a fractured shale and limey shale to chalk, which is a reservoir rock, but also its own source rock. The Frontier: a tight sandstone lying directly below the Niobrara, brought into contact with it by an unconformity. A basemap is presented with the seismic lines being analyzed for this project plus locations of 13 wells that we are using to supplement the analysis. The arrows point to two wells for which we have constructed synthetic seismograms.

  10. Using Carbon Dioxide to Enhance Recovery of Methane from Gas Hydrate Reservoirs: Final Summary Report

    SciTech Connect (OSTI)

    McGrail, B. Peter; Schaef, Herbert T.; White, Mark D.; Zhu, Tao; Kulkarni, Abhijeet S.; Hunter, Robert B.; Patil, Shirish L.; Owen, Antionette T.; Martin, P F.

    2007-09-01

    Carbon dioxide sequestration coupled with hydrocarbon resource recovery is often economically attractive. Use of CO2 for enhanced recovery of oil, conventional natural gas, and coal-bed methane are in various stages of common practice. In this report, we discuss a new technique utilizing CO2 for enhanced recovery of an unconventional but potentially very important source of natural gas, gas hydrate. We have focused our attention on the Alaska North Slope where approximately 640 Tcf of natural gas reserves in the form of gas hydrate have been identified. Alaska is also unique in that potential future CO2 sources are nearby, and petroleum infrastructure exists or is being planned that could bring the produced gas to market or for use locally. The EGHR (Enhanced Gas Hydrate Recovery) concept takes advantage of the physical and thermodynamic properties of mixtures in the H2O-CO2 system combined with controlled multiphase flow, heat, and mass transport processes in hydrate-bearing porous media. A chemical-free method is used to deliver a LCO2-Lw microemulsion into the gas hydrate bearing porous medium. The microemulsion is injected at a temperature higher than the stability point of methane hydrate, which upon contacting the methane hydrate decomposes its crystalline lattice and releases the enclathrated gas. Small scale column experiments show injection of the emulsion into a CH4 hydrate rich sand results in the release of CH4 gas and the formation of CO2 hydrate

  11. Evaluation and Effect of Fracturing Fluids on Fracture Conductivity in Tight Gas Reservoirs Using Dynamic Fracture Conductivity Test 

    E-Print Network [OSTI]

    Correa Castro, Juan

    2011-08-08

    concentrations under reservoirs conditions. The result of this study provides the basis to optimize the fracturing fluids and the polymer loading at different reservoir conditions, which may result in a clean and conductive fracture. Success in improving...

  12. Development of a 400 Level 3C Clamped Downhole Seismic Receiver Array for 3D Borehole Seismic Imaging of Gas Reservoirs

    SciTech Connect (OSTI)

    Bjorn N. P. Paulsson

    2006-09-30

    Borehole seismology is the highest resolution geophysical imaging technique available today to the oil and gas industry for characterization and monitoring of oil and gas reservoirs. However, the industry's ability to perform high resolution 3D imaging of deep and complex gas reservoirs using borehole seismology has been hampered by the lack of acquisition technology necessary to record large volumes of high frequency, high signal-to-noise-ratio borehole seismic data. This project took aim at this shortcoming by developing a 400 level 3C clamped downhole seismic receiver array, and accompanying software, for borehole seismic 3D imaging. This large borehole seismic array has removed the technical acquisition barrier for recording the data volumes necessary to do high resolution 3D VSP and 3D cross-well seismic imaging. Massive 3D VSP{reg_sign} and long range Cross-Well Seismology (CWS) are two of the borehole seismic techniques that promise to take the gas industry to the next level in their quest for higher resolution images of deep and complex oil and gas reservoirs. Today only a fraction of the oil or gas in place is produced when reservoirs are considered depleted. This is primarily due to our lack of understanding of detailed compartmentalization of oil and gas reservoirs. In this project, we developed a 400 level 3C borehole seismic receiver array that allows for economic use of 3D borehole seismic imaging for reservoir characterization and monitoring. This new array has significantly increased the efficiency of recording large data volumes at sufficiently dense spatial sampling to resolve reservoir complexities. The receiver pods have been fabricated and tested to withstand high temperature (200 C/400 F) and high pressure (25,000 psi), so that they can operate in wells up to 7,620 meters (25,000 feet) deep. The receiver array is deployed on standard production or drill tubing. In combination with 3C surface seismic or 3C borehole seismic sources, the 400 level receiver array can be used to obtain 3D 9C data. These 9C borehole seismic data provide both compressional wave and shear wave information that can be used for quantitative prediction of rock and pore fluid types. The 400-level borehole receiver array has been deployed successfully in a number of oil and gas wells during the course of this project, and each survey has resulted in marked improvements in imaging of geologic features that are critical for oil or gas production but were previously considered to be below the limits of seismic resolution. This added level of reservoir detail has resulted in improved well placement in the oil and gas fields that have been drilled using the Massive 3D VSP{reg_sign} images. In the future, the 400-level downhole seismic receiver array is expected to continue to improve reservoir characterization and drilling success in deep and complex oil and gas reservoirs.

  13. Radionuclide Migration at the Rio Blanco Site, A Nuclear-stimulated Low-permeability Natural Gas Reservoir

    SciTech Connect (OSTI)

    Clay A. Cooper; Ming Ye; Jenny Chapman; Craig Shirley

    2005-10-01

    The U.S. Department of Energy and its predecessor agencies conducted a program in the 1960s and 1970s that evaluated technology for the nuclear stimulation of low-permeability gas reservoirs. The third and final project in the program, Project Rio Blanco, was conducted in Rio Blanco County, in northwestern Colorado. In this experiment, three 33-kiloton nuclear explosives were simultaneously detonated in a single emplacement well in the Mesaverde Group and Fort Union Formation, at depths of 1,780, 1,899, and 2,039 m below land surface on May 17, 1973. The objective of this work is to estimate lateral distances that tritium released from the detonations may have traveled in the subsurface and evaluate the possible effect of postulated natural-gas development on radionuclide migration. Other radionuclides were considered in the analysis, but the majority occur in relatively immobile forms (such as nuclear melt glass). Of the radionuclides present in the gas phase, tritium dominates in terms of quantity of radioactivity in the long term and contribution to possible whole body exposure. One simulation is performed for {sup 85}Kr, the second most abundant gaseous radionuclide produced after tritium.

  14. Method for identifying subsurface fluid migration and drainage pathways in and among oil and gas reservoirs using 3-D and 4-D seismic imaging

    DOE Patents [OSTI]

    Anderson, Roger N. (New York, NY); Boulanger, Albert (New York, NY); Bagdonas, Edward P. (Brookline, MA); Xu, Liqing (New Milford, NJ); He, Wei (New Milford, NJ)

    1996-01-01

    The invention utilizes 3-D and 4-D seismic surveys as a means of deriving information useful in petroleum exploration and reservoir management. The methods use both single seismic surveys (3-D) and multiple seismic surveys separated in time (4-D) of a region of interest to determine large scale migration pathways within sedimentary basins, and fine scale drainage structure and oil-water-gas regions within individual petroleum producing reservoirs. Such structure is identified using pattern recognition tools which define the regions of interest. The 4-D seismic data sets may be used for data completion for large scale structure where time intervals between surveys do not allow for dynamic evolution. The 4-D seismic data sets also may be used to find variations over time of small scale structure within individual reservoirs which may be used to identify petroleum drainage pathways, oil-water-gas regions and, hence, attractive drilling targets. After spatial orientation, and amplitude and frequency matching of the multiple seismic data sets, High Amplitude Event (HAE) regions consistent with the presence of petroleum are identified using seismic attribute analysis. High Amplitude Regions are grown and interconnected to establish plumbing networks on the large scale and reservoir structure on the small scale. Small scale variations over time between seismic surveys within individual reservoirs are identified and used to identify drainage patterns and bypassed petroleum to be recovered. The location of such drainage patterns and bypassed petroleum may be used to site wells.

  15. Method for identifying subsurface fluid migration and drainage pathways in and among oil and gas reservoirs using 3-D and 4-D seismic imaging

    DOE Patents [OSTI]

    Anderson, R.N.; Boulanger, A.; Bagdonas, E.P.; Xu, L.; He, W.

    1996-12-17

    The invention utilizes 3-D and 4-D seismic surveys as a means of deriving information useful in petroleum exploration and reservoir management. The methods use both single seismic surveys (3-D) and multiple seismic surveys separated in time (4-D) of a region of interest to determine large scale migration pathways within sedimentary basins, and fine scale drainage structure and oil-water-gas regions within individual petroleum producing reservoirs. Such structure is identified using pattern recognition tools which define the regions of interest. The 4-D seismic data sets may be used for data completion for large scale structure where time intervals between surveys do not allow for dynamic evolution. The 4-D seismic data sets also may be used to find variations over time of small scale structure within individual reservoirs which may be used to identify petroleum drainage pathways, oil-water-gas regions and, hence, attractive drilling targets. After spatial orientation, and amplitude and frequency matching of the multiple seismic data sets, High Amplitude Event (HAE) regions consistent with the presence of petroleum are identified using seismic attribute analysis. High Amplitude Regions are grown and interconnected to establish plumbing networks on the large scale and reservoir structure on the small scale. Small scale variations over time between seismic surveys within individual reservoirs are identified and used to identify drainage patterns and bypassed petroleum to be recovered. The location of such drainage patterns and bypassed petroleum may be used to site wells. 22 figs.

  16. Study of Flow Regimes in Multiply-Fractured Horizontal Wells in Tight Gas and Shale Gas Reservoir Systems 

    E-Print Network [OSTI]

    Freeman, Craig M.

    2010-07-14

    Various analytical, semi-analytical, and empirical models have been proposed to characterize rate and pressure behavior as a function of time in tight/shale gas systems featuring a horizontal well with multiple hydraulic fractures. Despite a small...

  17. An Advisory System For Selecting Drilling Technologies and Methods in Tight Gas Reservoirs 

    E-Print Network [OSTI]

    Pilisi, Nicolas

    2010-01-16

    ranging between 177 Tcf and 379 Tcf. During the past few decades, gas production from tight sands field developments have taken place all around the world from South America (Argentina), Australia, Asia (China, Indonesia), the Russian Federation, Northern...

  18. Increasing Production from Low-Permeability Gas Reservoirs by Optimizing Zone Isolation for Successful Stimulation Treatments

    SciTech Connect (OSTI)

    Fred Sabins

    2005-03-31

    Maximizing production from wells drilled in low-permeability reservoirs, such as the Barnett Shale, is determined by cementing, stimulation, and production techniques employed. Studies show that cementing can be effective in terms of improving fracture effectiveness by 'focusing' the frac in the desired zone and improving penetration. Additionally, a method is presented for determining the required properties of the set cement at various places in the well, with the surprising result that uphole cement properties in wells destined for multiple-zone fracturing is more critical than those applied to downhole zones. Stimulation studies show that measuring pressure profiles and response during Pre-Frac Injection Test procedures prior to the frac job are critical in determining if a frac is indicated at all, as well as the type and size of the frac job. This result is contrary to current industry practice, in which frac jobs are designed well before the execution, and carried out as designed on location. Finally, studies show that most wells in the Barnett Shale are production limited by liquid invasion into the wellbore, and determinants are presented for when rod or downhole pumps are indicated.

  19. Discovery of Large Molecular Gas Reservoirs in Post-Starburst Galaxies

    E-Print Network [OSTI]

    French, K Decker; Zabludoff, Ann; Narayanan, Desika; Shirley, Yancy; Walter, Fabian; Smith, John-David; Tremonti, Christy A

    2015-01-01

    Post-starburst (or "E+A") galaxies are characterized by low H$\\alpha$ emission and strong Balmer absorption, suggesting a recent starburst, but little current star formation. Although many of these galaxies show evidence of recent mergers, the mechanism for ending the starburst is not yet understood. To study the fate of the molecular gas, we search for CO (1-0) and (2-1) emission with the IRAM 30m and SMT 10m telescopes in 32 nearby ($0.01gas masses of $M(H_2)=10^{8.6}$-$10^{9.8} M_\\odot$ and molecular gas mass to stellar mass fractions of $\\sim10^{-2}$-$10^{-0.5}$, comparable to those of star-forming galaxies. The large amounts of molecular gas rule out complete gas consumption, expulsion, or starvation as the primary mechanism that ends the starburst in these galaxies. The upper limits on $M(H_2)$ for th...

  20. Alabama Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)Decade Year-0ProvedDecade Year-0Cubic(Million CubicWorking Gas1) Part

  1. Florida Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr May Jun20032,485,331Gas2001

  2. Louisiana Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr 2012 2013(Million Barrels) Natural Gas8 0 0 0

  3. Effect of flue gas impurities on the process of injection and storage of carbon dioxide in depleted gas reservoirs 

    E-Print Network [OSTI]

    Nogueira de Mago, Marjorie Carolina

    2005-11-01

    Previous experiments - injecting pure CO2 into carbonate cores - showed that the process is a win-win technology, sequestrating CO2 while recovering a significant amount of hitherto unrecoverable natural gas that could help defray the cost of CO2...

  4. Optimal Process Design for Coupled CO2 Sequestration and Enhanced Gas Recovery in Carbonate Reservoirs 

    E-Print Network [OSTI]

    Odi, Uchenna

    2013-12-09

    ........................................................................................................ 26 Figure 11: PVT System for Dew Point Measurement (a) Oven (b) Computer Data Gathering Equipment (c) Top Pump B (d) PVT Visual Cell (e) Bottom Pump A... adequate understanding of condensate blockage and its interaction with CO2. Accomplishing this requires a fundamental understanding of the pressure, volume, and temperature (PVT) interactions between gas condensate and CO2. Discerning these PVT...

  5. Rate Transient Analysis in Shale Gas Reservoirs with Transient Linear Behavior 

    E-Print Network [OSTI]

    Bello, Rasheed O.

    2010-07-14

    of the Major United States Shale Basins............................................ 3 1.3 Microseismic Map of Multi-Stage Hydraulically Fractured Horizontal Well... micro-seismic data used to monitor the hydraulic fractures is shown in Fig. 1.3. The different hydraulic fracture stages are indicated by the different clusters. Shale gas production data from a sample well in the Barnett shale is plotted against...

  6. New Reservoir Discoveries in Old Fields of Natural Gas, Wet After Lease

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Marthrough 1996)Price780 922

  7. U.S. Natural Gas Plant Liquids, New Reservoir Discoveries in Old Fields

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)Decade Year-0Proved ReservesData2009 2010Year Jan Feb Mar2009 2010(Million

  8. Alaska Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)Decade Year-0ProvedDecade2,948 2,724 2,570 2,304 1,670Same0 1 2Cubic3,566

  9. Arkansas Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)Decade Year-0ProvedDecade2,948 2,724 2,570MonthThousand8 0.8 0.8 0.622 28 21

  10. Associated-Dissolved Natural Gas New Reservoir Discoveries in Old Fields,

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)Decade Year-0ProvedDecade2,948 2,724per Thousand CubicSeparation, 263 102

  11. California Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)Decade Year-0ProvedDecade2,948 2,724per ThousandLease0Year Jan,835 2,939

  12. Colorado Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)Decade Year-0ProvedDecade2,948CaliforniaFeet) (Million,914 1,886Cubic

  13. Kansas Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr MayYearYearDecade Year-0163 258 228 183 189 21164

  14. Kentucky Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr 2012 2013 2014 View Historyto7 2005-2014

  15. Michigan Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr 2012DecadeTotal ConsumptionperYear Jan

  16. Montana Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    Gasoline and Diesel Fuel Update (EIA)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural GasAdjustments (Billion Cubic Feet)DecadeYear Jan Feb Mar Apr 2012DecadeTotal19FuelYear5) Model37 64 25 11 16

  17. Wyoming Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion

    U.S. Energy Information Administration (EIA) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of Natural Gas Production3,1,50022,3,,0,,6,1,6,1,50022,3,,,,6,1,8,1,50022,3,,,,6,1,9,1,50022,3,,,,6,1,Separation 362855

  18. Hydroelectric Reservoirs -the Carbon Dioxide and Methane

    E-Print Network [OSTI]

    Fischlin, Andreas

    Hydroelectric Reservoirs - the Carbon Dioxide and Methane Emissions of a "Carbon Free" Energy an overview on the greenhouse gas production of hydroelectric reservoirs. The goals are to point out the main how big the greenhouse gas emissions from hydroelectric reservoirs are compared to thermo-power plants

  19. Optimizing injected solvent fraction in stratified reservoirs 

    E-Print Network [OSTI]

    Moon, Gary Michael

    1993-01-01

    Waterflooding has become standard practice for extending the productive life of many solution gas drive reservoirs, but has the disadvantage of leaving a substantial residual oil volume in the reservoir. Solvent flooding has been offered as a...

  20. Numerical simulations of the Macondo well blowout reveal strong control of oil flow by reservoir permeability and exsolution of gas

    E-Print Network [OSTI]

    Oldenburg, C.M.

    2013-01-01

    for estimates of the oil and gas flow rate from the Macondoteam and carried out oil and gas flow simulations using theoil-gas system. The flow of oil and gas was simulated using

  1. Numerical simulations of the Macondo well blowout reveal strong control of oil flow by reservoir permeability and exsolution of gas

    E-Print Network [OSTI]

    Oldenburg, C.M.

    2013-01-01

    for estimates of the oil and gas flow rate from the Macondooil-gas system. The flow of oil and gas was simulated usingmaximal flow rates of oil and gas. With the conceptual model

  2. Integrated seismic study of naturally fractured tight gas reservoirs. Technical progress report for the period: 7/1/93--9/31/93

    SciTech Connect (OSTI)

    Mavko, G.; Nur, A.

    1993-10-23

    The study area is located at the southern end of the Powder River Basin in Converse County in east-central Wyoming. It is a low permeability fractured site, with both gas and oil present. Reservoirs are highly compartmentalized due to the low permeabilities, and fractures provide the only practical paths of production. During this eighth quarter of the seismic study of this area, work continued in processing seismic data, collecting additional geological information to aid in the interpretation, and integrating regional structural information and fracture trends with observations of structure in the study area.

  3. Please cite this article in press as: Gilfillan, S.M.V., et al., He and Ne as tracers of natural CO2 migration up a fault from a deep reservoir. Int. J. Greenhouse Gas Control (2011), doi:10.1016/j.ijggc.2011.08.008

    E-Print Network [OSTI]

    Wilkinson, Mark

    2011-01-01

    in the deep reservoir, can be traced along a fault plane to occur in waters from both groundwater wells2 migration up a fault from a deep reservoir. Int. J. Greenhouse Gas Control (2011), doi:10.1016/j migration up a fault from a deep reservoir Stuart M.V. Gilfillana, , Mark Wilkinsona , R. Stuart Haszeldinea

  4. Integrated seismic study of naturally fractured tight gas reservoirs. Technical progress report, October 1, 1993--December 31, 1993

    SciTech Connect (OSTI)

    Mavko, G.; Nur, A.

    1994-01-29

    This was the ninth quarter of the contract. During this quarter we (1) continued processing the seismic data, (2) collected additional logs to aid in the interpretation, and (3)began modeling some of the P-wave amplitude anomalies that we see in the data. The study area is located at the southern end of the powder river Basin in Converse county in east-central Wyoming. It is a low permeability fractured site, with both has and oil present. Reservoirs are highly compartmentalized due tot he low permeabilities, and fractures provide the only practical drainage paths for production. The two formations of interest are: The Niobrara; a fractured shale and limey shale to chalk, which is a reservoir rock, but also its own source rock. The Frontier, a tight sandstone lying directly below the Niobrara, brought into contract with it by an unconformity.

  5. SMALL, GEOLOGICALLY COMPLEX RESERVOIRS CAN BENEFIT FROM RESERVOIR SIMULATION

    SciTech Connect (OSTI)

    Richard E. Bennett

    2002-06-24

    The Cascade Sand zone of the Mission-Visco Lease in the Cascade Oil field of Los Angeles County, California, has been under water flood since 1970. Increasing water injection to increase oil production rates was being considered as an opportunity to improve oil recovery. However, a secondary gas cap had formed in the up-dip portion of the reservoir with very low gas cap pressures, creating concern that oil could be displaced into the gas cap resulting in the loss of recoverable oil. Therefore, injecting gas into the gas cap to keep the gas cap pressurized and restrict the influx of oil during water injection was also being considered. Further, it was recognized that the reservoir geology in the gas cap area is very complex with numerous folding and faulting and thus there are potential pressure barriers in several locations throughout the reservoir. With these conditions in mind, there were concerns regarding well to well continuity in the gas cap, which could interfere with the intended repressurization impact. Concerns about the pattern of gas flow from well to well, the possibilities of cycling gas without the desired increased pressure, and the possible loss of oil displaced into the gas cap resulted in the decision to conduct a gas tracer survey in an attempt to better define inter-well communication. Following the gas tracer survey, a reservoir model would be developed to integrate the findings of the gas tracer survey, known geologic and reservoir data, and historic production data. The reservoir model would be used to better define the reservoir characteristics and provide information that could help optimize the waterflood-gas injection project under consideration for efficient water and gas injection management to increase oil production. However, due to inadequate gas sampling procedures in the field and insufficiently developed laboratory analytical techniques, the laboratory was unable to detect the tracer in the gas samples taken. At that point, focus on, and an expansion of the scope of the reservoir simulation and modeling effort was initiated, using DOE's BOAST98 (a visual, dynamic, interactive update of BOAST3), 3D, black oil reservoir simulation package as the basis for developing the reservoir model. Reservoir characterization, modeling, and reservoir simulation resulted in a significant change in the depletion strategy. Information from the reservoir characterization and modeling effort indicate that in-fill drilling and relying on natural water influx from the aquifer could increase remaining reserves by 125,000 barrels of oil per well, and that up to 10 infill wells could be drilled in the field. Through this scenario, field production could be increased two to three times over the current 65 bopd. Based on the results of the study, permits have been applied for to drill a directional infill well to encounter the productive zone at a high angle in order to maximize the amount of pay and reservoirs encountered.

  6. Seismic low-frequency effects from oil-saturated reservoir zones

    E-Print Network [OSTI]

    Goloshubin, Gennady M.; Korneev, Valeri A.; Vingalov, Vjacheslav M.

    2002-01-01

    and gas saturation changes in underground reservoirs. Whilereservoir for the cases of oil and water saturation.

  7. Petroleum Engineering 310 Reservoir Fluids

    E-Print Network [OSTI]

    of oilfield brine properties: Salinity, Bubble Point, formation volume factor, density and solution gas water12 Petroleum Engineering 310 Reservoir Fluids Credit 4: (3-3) Required for Juniors Catalog: Gas Formation Volume Factor. Viscosity. Wet Gas Gravity and Isothermal Compressibility. 5. Definition

  8. CO2 gas/oil ratio prediction in a multi-component reservoir bycombined seismic and electromagnetic imaging

    SciTech Connect (OSTI)

    Hoversten, G.M.; Gritto, Roland; Washbourne, John; Daley, Tom

    2002-08-28

    Crosswell seismic and electromagnetic data sets taken before and during CO2 flooding of an oil reservoir are inverted to produce crosswell images of the change in compressional velocity, shear velocity and electrical conductivity during a CO2 injection pilot study. A rock properties model is developed using measured log porosity, fluid saturations, pressure, temperature, bulk density, sonic velocity and electrical conductivity. The parameters of the rock properties model are found by an L1-norm simplex minimization of predicted and observed compressional velocity and density. A separate minimization using Archie's law provides parameters for modeling the relations between water saturation, porosity and the electrical conductivity. The rock properties model is used to generate relationships between changes in geophysical parameters and changes in reservoir parameters. The electrical conductivity changes are directly mapped to changes in water saturation. The estimated changes in water saturation are used with the observed changes in shear wave velocity to predict changes in reservoir pressure. The estimation of the spatial extent and amount of CO2 relies on first removing the effects of the water saturation and pressure changes from the observed compressional velocity changes, producing a residual compressional velocity change. The residual compressional velocity change is then interpreted in terms of increases in the CO2 /oil ratio. Resulting images of CO2/oil ratio show CO2 rich zones that are well correlated with the location of injection perforations with the size of these zones also correlating to the amount of injected CO2. The images produced by this process are better correlated to the location and amount of injected CO2 than are any of the individual images of change in geophysical parameters.

  9. Application of the transient, isochronal p/z plotting method to multilayered reservoirs 

    E-Print Network [OSTI]

    Dandekar, Rashmin Ramesh

    1992-01-01

    of the crossflow reservoir cases was lower than the error for the corresponding commingled reservoir cases. The error in gas- The error in gas-in-place estimates in all of the crossflow reservoir cases was lower than the error for the corresponding commingled... reservoir cases. The ermr in gas- in-place estimate decreases with increasing permeability contrast. The behavior can be attributed to the fact that crossflow reservoir behavior is similar to the behavior of homogeneous reservoir after the passage...

  10. Sequestration of CO2 in the Altmark natural gas field, Germany: Mobility control to extend enhanced gas recovery

    E-Print Network [OSTI]

    Rebscher, D.; May, F.; Oldenburg, C.M.

    2006-01-01

    OF CO 2 IN THE ALTMARK NATURAL GAS FIELD, GERMANY: MOBILITYin the depleted Altmark natural gas reservoir, Germany. Ourdioxide or nitrogen in natural gas (methane) reservoirs,

  11. Uncertainty quantification of volumetric and material balance analysis of gas reservoirs with water influx using a Bayesian framework 

    E-Print Network [OSTI]

    Aprilia, Asti Wulandari

    2007-04-25

    Accurately estimating hydrocarbon reserves is important, because it affects every phase of the oil and gas business. Unfortunately, reserves estimation is always uncertain, since perfect information is seldom available ...

  12. A Hierarchical Multiscale Approach to History Matching and Optimization for Reservoir Management in Mature Fields 

    E-Print Network [OSTI]

    Park, Han-Young

    2012-10-19

    Reservoir management typically focuses on maximizing oil and gas recovery from a reservoir based on facts and information while minimizing capital and operating investments. Modern reservoir management uses history-matched simulation model...

  13. High-resolution geostatistical inversion of a seismic data set acquired in a Gulf of Mexico gas reservoir.

    E-Print Network [OSTI]

    Torres-Verdín, Carlos

    High-resolution geostatistical inversion of a seismic data set acquired in a Gulf of Mexico gas, UNOCAL Corporation Summary Geostatistical inversion is applied on a Gulf-of-Mexico, 3D post-stack seismic in this paper is located in the Gulf of Mexico, off the coast of Louisiana. Existing development wells reach two

  14. Integrated Reservoir Characterization: Offshore Louisiana, Grand Isle Blocks 32 & 33 

    E-Print Network [OSTI]

    Casey, Michael Chase

    2011-08-08

    This thesis integrated geology, geophysics, and petroleum engineering data to build a detailed reservoir characterization models for three gas pay sands in the Grand Isle 33 & 43 fields, offshore Louisiana. The reservoirs are Late Miocene in age...

  15. Diagnosis of "fizz-gas" and gas reservoirs in deep-water environment De-hua Han, X RPL, Houston Unversity

    E-Print Network [OSTI]

    .78) 0 500 1000 1500 2000 2500 3000 3500 0 20 40 60 80 10 Brine Volume (%) Modulas(Mpa 0 6.9Mpa, 20C 34.5Mpa, 40C 69Mpa, 70C 103.5Mpa, 90C Oil Mixture of brine (50000ppm) & gas (0.78) 0 500 1000 1500 2000Mixture of brine (50000ppm) & gas (0.78) 0 500 1000 1500 2000 2500 3000 3500 0 20 40 60 80 10 Brine Volume

  16. Analysis of real-time reservoir monitoring : reservoirs, strategies, & modeling.

    SciTech Connect (OSTI)

    Mani, Seethambal S.; van Bloemen Waanders, Bart Gustaaf; Cooper, Scott Patrick; Jakaboski, Blake Elaine; Normann, Randy Allen; Jennings, Jim; Gilbert, Bob; Lake, Larry W.; Weiss, Chester Joseph; Lorenz, John Clay; Elbring, Gregory Jay; Wheeler, Mary Fanett; Thomas, Sunil G.; Rightley, Michael J.; Rodriguez, Adolfo; Klie, Hector; Banchs, Rafael; Nunez, Emilio J.; Jablonowski, Chris

    2006-11-01

    The project objective was to detail better ways to assess and exploit intelligent oil and gas field information through improved modeling, sensor technology, and process control to increase ultimate recovery of domestic hydrocarbons. To meet this objective we investigated the use of permanent downhole sensors systems (Smart Wells) whose data is fed real-time into computational reservoir models that are integrated with optimized production control systems. The project utilized a three-pronged approach (1) a value of information analysis to address the economic advantages, (2) reservoir simulation modeling and control optimization to prove the capability, and (3) evaluation of new generation sensor packaging to survive the borehole environment for long periods of time. The Value of Information (VOI) decision tree method was developed and used to assess the economic advantage of using the proposed technology; the VOI demonstrated the increased subsurface resolution through additional sensor data. Our findings show that the VOI studies are a practical means of ascertaining the value associated with a technology, in this case application of sensors to production. The procedure acknowledges the uncertainty in predictions but nevertheless assigns monetary value to the predictions. The best aspect of the procedure is that it builds consensus within interdisciplinary teams The reservoir simulation and modeling aspect of the project was developed to show the capability of exploiting sensor information both for reservoir characterization and to optimize control of the production system. Our findings indicate history matching is improved as more information is added to the objective function, clearly indicating that sensor information can help in reducing the uncertainty associated with reservoir characterization. Additional findings and approaches used are described in detail within the report. The next generation sensors aspect of the project evaluated sensors and packaging survivability issues. Our findings indicate that packaging represents the most significant technical challenge associated with application of sensors in the downhole environment for long periods (5+ years) of time. These issues are described in detail within the report. The impact of successful reservoir monitoring programs and coincident improved reservoir management is measured by the production of additional oil and gas volumes from existing reservoirs, revitalization of nearly depleted reservoirs, possible re-establishment of already abandoned reservoirs, and improved economics for all cases. Smart Well monitoring provides the means to understand how a reservoir process is developing and to provide active reservoir management. At the same time it also provides data for developing high-fidelity simulation models. This work has been a joint effort with Sandia National Laboratories and UT-Austin's Bureau of Economic Geology, Department of Petroleum and Geosystems Engineering, and the Institute of Computational and Engineering Mathematics.

  17. The Optimization of Well Spacing in a Coalbed Methane Reservoir 

    E-Print Network [OSTI]

    Sinurat, Pahala Dominicus

    2012-02-14

    , such as rank of the coal, coal composition, micropores structure, reservoir pressure, molecular properties of gas adsorbed on the internal surface of coal seam, and reservoir temperature3,7. An idealized model of coalbed methane reservoir consists of a... making process. The uncertainties include the coal density, permeability or gas content as parameters of coal properties. Each coalbed methane reservoir property will govern production performance in a certain degree. Some parameters strongly influence...

  18. FRACTURED PETROLEUM RESERVOIRS

    SciTech Connect (OSTI)

    Abbas Firoozabadi

    1999-06-11

    The four chapters that are described in this report cover a variety of subjects that not only give insight into the understanding of multiphase flow in fractured porous media, but they provide also major contribution towards the understanding of flow processes with in-situ phase formation. In the following, a summary of all the chapters will be provided. Chapter I addresses issues related to water injection in water-wet fractured porous media. There are two parts in this chapter. Part I covers extensive set of measurements for water injection in water-wet fractured porous media. Both single matrix block and multiple matrix blocks tests are covered. There are two major findings from these experiments: (1) co-current imbibition can be more efficient than counter-current imbibition due to lower residual oil saturation and higher oil mobility, and (2) tight fractured porous media can be more efficient than a permeable porous media when subjected to water injection. These findings are directly related to the type of tests one can perform in the laboratory and to decide on the fate of water injection in fractured reservoirs. Part II of Chapter I presents modeling of water injection in water-wet fractured media by modifying the Buckley-Leverett Theory. A major element of the new model is the multiplication of the transfer flux by the fractured saturation with a power of 1/2. This simple model can account for both co-current and counter-current imbibition and computationally it is very efficient. It can be orders of magnitude faster than a conventional dual-porosity model. Part II also presents the results of water injection tests in very tight rocks of some 0.01 md permeability. Oil recovery from water imbibition tests from such at tight rock can be as high as 25 percent. Chapter II discusses solution gas-drive for cold production from heavy-oil reservoirs. The impetus for this work is the study of new gas phase formation from in-situ process which can be significantly different from that of gas displacement processes. The work is of experimental nature and clarifies several misconceptions in the literature. Based on experimental results, it is established that the main reason for high efficiency of solution gas drive from heavy oil reservoirs is due to low gas mobility. Chapter III presents the concept of the alteration of porous media wettability from liquid-wetting to intermediate gas-wetting. The idea is novel and has not been introduced in the petroleum literature before. There are significant implications from such as proposal. The most direct application of intermediate gas wetting is wettability alteration around the wellbore. Such an alteration can significantly improve well deliverability in gas condensate reservoirs where gas well deliverability decreases below dewpoint pressure. Part I of Chapter III studies the effect of gravity, viscous forces, interfacial tension, and wettability on the critical condensate saturation and relative permeability of gas condensate systems. A simple phenomenological network model is used for this study, The theoretical results reveal that wettability significantly affects both the critical gas saturation and gas relative permeability. Gas relative permeability may increase ten times as contact angle is altered from 0{sup o} (strongly liquid wet) to 85{sup o} (intermediate gas-wetting). The results from the theoretical study motivated the experimental investigation described in Part II. In Part II we demonstrate that the wettability of porous media can be altered from liquid-wetting to gas-wetting. This part describes our attempt to find appropriate chemicals for wettability alteration of various substrates including rock matrix. Chapter IV provides a comprehensive treatment of molecular, pressure, and thermal diffusion and convection in porous media Basic theoretical analysis is presented using irreversible thermodynamics.

  19. Exact solutions in a model of vertical gas migration

    E-Print Network [OSTI]

    Silin, Dmitriy B.; Patzek, Tad W.; Benson, Sally M.

    2006-01-01

    gas leaking from seasonal gas storage, or for modeling ofmigration resulting from a gas storage leak, the gas ?owsof gas, created by a leaking gas storage reservoir, migrates

  20. Development of Reservoir Characterization Techniques and Production Models for Exploiting Naturally Fractured Reservoirs

    SciTech Connect (OSTI)

    Wiggins, Michael L.; Brown, Raymon L.; Civan, Faruk; Hughes, Richard G.

    2003-02-11

    This research was directed toward developing a systematic reservoir characterization methodology which can be used by the petroleum industry to implement infill drilling programs and/or enhanced oil recovery projects in naturally fractured reservoir systems in an environmentally safe and cost effective manner. It was anticipated that the results of this research program will provide geoscientists and engineers with a systematic procedure for properly characterizing a fractured reservoir system and a reservoir/horizontal wellbore simulator model which can be used to select well locations and an effective EOR process to optimize the recovery of the oil and gas reserves from such complex reservoir systems.

  1. Estimation of original gas in place from short-term shut-in pressure data for commingled tight gas reservoirs with no crossflow 

    E-Print Network [OSTI]

    Khuong, Chan Hung

    1995-01-01

    -in pressure data; namely one-point (secant), two-point (tangent), curve fitting, and type curve methods. A two dimensional dry gas simulator (GASSIM simulator) was used in this study. The wellbore storage, non-darcy flow, and backflow phenomenon during shut...

  2. Occurrence of gas hydrate in Oligocene Frio sand: Alaminos Canyon Block 818: Northern Gulf of Mexico

    E-Print Network [OSTI]

    Boswell, R.D.

    2010-01-01

    of the reservoir with gas hydrate saturation in excess ofquality reservoirs, consistent with the lower saturationssaturation remains uniformly high wherever the Frio reservoir

  3. Predicting reservoir sedimentation 

    E-Print Network [OSTI]

    Wooten, Stephanie

    1997-01-01

    Sediments accumulate in reservoirs and significantly decrease storage capacity. Predicting sedimentation is an important consideration in the design of new reservoir projects and in the management of existing reservoirs. Sedimentation rates may vary...

  4. Numerical Investigation of Fractured Reservoir Response to Injection/Extraction Using a Fully Coupled Displacement Discontinuity Method 

    E-Print Network [OSTI]

    Lee, Byungtark

    2011-10-21

    In geothermal reservoirs and unconventional gas reservoirs with very low matrix permeability, fractures are the main routes of fluid flow and heat transport, so the fracture permeability change is important. In fact, reservoir development under...

  5. Using time-lapse seismics as a reservoir-monitoring tool, geophysics can help distinguish different reservoir pro-

    E-Print Network [OSTI]

    reservoir pro- duction scenarios. For example, Eiken et al. (2000) success- fully detected fluid-saturation life, oil saturation usually decreases, reservoir pressure declines, and gas breakout may occurUsing time-lapse seismics as a reservoir-monitoring tool, geophysics can help distinguish different

  6. Society of Petroleum Engineers Staggered In Time Coupling of Reservoir Flow Simulation and Geomechanical Defor-

    E-Print Network [OSTI]

    Minkoff, Susan E.

    ) the flow of oil, gas, and water fluid phases in the reservoir while the lat- ter has been specialized

  7. Simulation of naturally fractured reservoirs

    SciTech Connect (OSTI)

    Saidi, A.M.

    1983-11-01

    A three-dimensional, three-phase reservoir simulator was developed to study the behavior of fully or partially fractured reservoirs. It is also demonstrated, that when a fractured reservoir is subject to a relatively large rate of pressure drop and/or it composed of relatively large blocks, the pseudo steady-state pressure concept gives large errors as compared with transient fromulation. In addition, when gravity drainage and imbibitum processes, which is the most important mechanism in the fractured reservoirs, are represented by a ''lumped parameter'' even larger errors can be produced in exchange flow between matrix and fractures. For these reasons, the matrix blocks are gridded and the transfer between matrix and fractures are calculated using pressure and diffusion transient concept. In this way the gravity drainage is also calculated accurately. As the matrix-fracture exchange flow depends on the location of each matrix grid relative to the GOC and/or WOC in fracture, the exchange flow equation are derived and given for each possible case. The differential equation describing the flow of water, oil, and gas within the matrix and fracture system, each of which may contain six unknowns, are presented. The two sets of equations are solved implicitly for pressure water, and gas stauration in both matrix and fractures. The first twenty two years of the history of Haft Kel field was successfully matched with this model and the results are included.

  8. Status of Norris Reservoir

    SciTech Connect (OSTI)

    Not Available

    1990-09-01

    This is one in a series of reports prepared by the Tennessee Valley Authority (TVA) for those interested in the conditions of TVA reservoirs. This overview of Norris Reservoir summarizes reservoir and watershed characteristics, reservoir uses, conditions that impair reservoir uses, water quality and aquatic biological conditions, and activities of reservoir management agencies. This information was extracted from the most up-to-date publications and data available, and from interviews with water resource professionals in various federal, state, and local agencies, and in public and private water supply and wastewater treatment facilities. 14 refs., 3 figs.

  9. Reservoir Characterization Research Laboratory

    E-Print Network [OSTI]

    Texas at Austin, University of

    Reservoir Characterization Research Laboratory for Carbonate Studies Executive Summary for 2014 Outcrop and Subsurface Characterization of Carbonate Reservoirs for Improved Recovery of Remaining/Al 0.00 0.02 0.04 Eagle Ford Fm #12;#12; Reservoir Characterization Research Laboratory Research Plans

  10. Socioeconomic impact of infill drilling recovery from carbonate reservoirs in the Permian Basin, West Texas 

    E-Print Network [OSTI]

    Jagoe, Bryan Keith

    1994-01-01

    This investigative study presents results on the socioeconomic impact of infill drilling recovery from carbonate reservoirs in the Permian Basin. The amount of incremental oil and gas production from infill drilling in 37 carbonate reservoir units...

  11. Data quality enhancement in oil reservoir operations : an application of IPMAP

    E-Print Network [OSTI]

    Lin, Paul Hong-Yi

    2012-01-01

    This thesis presents a study of data quality enhancement opportunities in upstream oil and gas industry. Information Product MAP (IPMAP) methodology is used in reservoir pressure and reservoir simulation data, to propose ...

  12. Status of Wheeler Reservoir

    SciTech Connect (OSTI)

    Not Available

    1990-09-01

    This is one in a series of status reports prepared by the Tennessee Valley Authority (TVA) for those interested in the conditions of TVA reservoirs. This overview of Wheeler Reservoir summarizes reservoir purposes and operation, reservoir and watershed characteristics, reservoir uses and use impairments, and water quality and aquatic biological conditions. The information presented here is from the most recent reports, publications, and original data available. If no recent data were available, historical data were summarized. If data were completely lacking, environmental professionals with special knowledge of the resource were interviewed. 12 refs., 2 figs.

  13. Status of Cherokee Reservoir

    SciTech Connect (OSTI)

    Not Available

    1990-08-01

    This is the first in a series of reports prepared by Tennessee Valley Authority (TVA) for those interested in the conditions of TVA reservoirs. This overviews of Cherokee Reservoir summarizes reservoir and watershed characteristics, reservoir uses and use impairments, water quality and aquatic biological conditions, and activities of reservoir management agencies. This information was extracted from the most current reports, publications, and data available, and interviews with water resource professionals in various Federal, state, and local agencies and in public and private water supply and wastewater treatment facilities. 11 refs., 4 figs., 1 tab.

  14. Numerical modeling of gas migration into and through faulted sand reservoirs in Pabst Field (Main Pass East Block 259), northern Gulf of Mexico 

    E-Print Network [OSTI]

    Li, Yuqian

    2006-08-16

    allow gas communication among the sands. Meanwhile, three fault families break up the three sands into numerous compartments. A primary fault and large synthetic and antithetic faults act as gas migration pathways: the synthetic and antithetic faults...

  15. New Mexico Associated-Dissolved Natural Gas, Reserves in Nonproducing...

    U.S. Energy Information Administration (EIA) Indexed Site

    Reserves in Nonproducing Reservoirs, Wet (Billion Cubic Feet) New Mexico Associated-Dissolved Natural Gas, Reserves in Nonproducing Reservoirs, Wet (Billion Cubic Feet) Decade...

  16. New Mexico Natural Gas Wet After Lease Separation, Reserves in...

    U.S. Energy Information Administration (EIA) Indexed Site

    After Lease Separation, Reserves in Nonproducing Reservoirs (Billion Cubic Feet) New Mexico Natural Gas Wet After Lease Separation, Reserves in Nonproducing Reservoirs (Billion...

  17. New Mexico Nonassociated Natural Gas, Reserves in Nonproducing...

    U.S. Energy Information Administration (EIA) Indexed Site

    Reserves in Nonproducing Reservoirs, Wet (Billion Cubic Feet) New Mexico Nonassociated Natural Gas, Reserves in Nonproducing Reservoirs, Wet (Billion Cubic Feet) Decade Year-0...

  18. New Mexico Natural Gas Liquids Lease Condensate, Reserves in...

    U.S. Energy Information Administration (EIA) Indexed Site

    in Nonproducing Reservoirs (Million Barrels) New Mexico Natural Gas Liquids Lease Condensate, Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  19. SEISMIC ATTENUATION FOR RESERVOIR CHARACTERIZATION

    SciTech Connect (OSTI)

    Joel Walls; M.T. Taner; Naum Derzhi; Gary Mavko; Jack Dvorkin

    2003-12-01

    We have developed and tested technology for a new type of direct hydrocarbon detection. The method uses inelastic rock properties to greatly enhance the sensitivity of surface seismic methods to the presence of oil and gas saturation. These methods include use of energy absorption, dispersion, and attenuation (Q) along with traditional seismic attributes like velocity, impedance, and AVO. Our approach is to combine three elements: (1) a synthesis of the latest rock physics understanding of how rock inelasticity is related to rock type, pore fluid types, and pore microstructure, (2) synthetic seismic modeling that will help identify the relative contributions of scattering and intrinsic inelasticity to apparent Q attributes, and (3) robust algorithms that extract relative wave attenuation attributes from seismic data. This project provides: (1) Additional petrophysical insight from acquired data; (2) Increased understanding of rock and fluid properties; (3) New techniques to measure reservoir properties that are not currently available; and (4) Provide tools to more accurately describe the reservoir and predict oil location and volumes. These methodologies will improve the industry's ability to predict and quantify oil and gas saturation distribution, and to apply this information through geologic models to enhance reservoir simulation. We have applied for two separate patents relating to work that was completed as part of this project.

  20. MULTIDISCIPLINARY IMAGING OF ROCK PROPERTIES IN CARBONATE RESERVOIRS FOR FLOW-UNIT TARGETING

    SciTech Connect (OSTI)

    Stephen C. Ruppel

    2005-02-01

    Despite declining production rates, existing reservoirs in the US contain large quantities of remaining oil and gas that constitute a huge target for improved diagnosis and imaging of reservoir properties. The resource target is especially large in carbonate reservoirs, where conventional data and methodologies are normally insufficient to resolve critical scales of reservoir heterogeneity. The objectives of the research described in this report were to develop and test such methodologies for improved imaging, measurement, modeling, and prediction of reservoir properties in carbonate hydrocarbon reservoirs. The focus of the study is the Permian-age Fullerton Clear Fork reservoir of the Permian Basin of West Texas. This reservoir is an especially appropriate choice considering (a) the Permian Basin is the largest oil-bearing basin in the US, and (b) as a play, Clear Fork reservoirs have exhibited the lowest recovery efficiencies of all carbonate reservoirs in the Permian Basin.

  1. Optimization of fractured well performance of horizontal gas wells 

    E-Print Network [OSTI]

    Magalhaes, Fellipe Vieira

    2009-06-02

    In low-permeability gas reservoirs, horizontal wells have been used to increase the reservoir contact area, and hydraulic fracturing has been further extending the contact between wellbores and reservoirs. This thesis presents an approach...

  2. Reservoir CharacterizationReservoir Characterization Research LaboratoryResearch Laboratory

    E-Print Network [OSTI]

    Texas at Austin, University of

    Reservoir CharacterizationReservoir Characterization Research LaboratoryResearch Laboratory at Austin Austin, Texas 78713Austin, Texas 78713--89248924 #12;Reservoir Characterization Research Laboratory for Carbonate Studies Research Plans for 2012 Outcrop and Subsurface Characterization of Carbonate

  3. A New Method for History Matching and Forecasting Shale Gas/Oil Reservoir Production Performance with Dual and Triple Porosity Models 

    E-Print Network [OSTI]

    Samandarli, Orkhan

    2012-10-19

    Different methods have been proposed for history matching production of shale gas/oil wells which are drilled horizontally and usually hydraulically fractured with multiple stages. These methods are simulation, analytical models, and empirical...

  4. Relevance of underground natural gas storage to geologic sequestration of carbon dioxide

    E-Print Network [OSTI]

    Lippmann, Marcelo J.; Benson, Sally M.

    2002-01-01

    http://www.eia.doe.gov/oil_gas/natural_gas/info_glance/underground in depleted oil and gas reservoirs and brinestorage projects. Depleted oil and gas reservoirs and brine

  5. Reactive Transport Modeling and Geophysical Monitoring of Bioclogging at Reservoir Scale

    E-Print Network [OSTI]

    Hubbard, Susan

    in this study was on developing a systematic approach to understand and monitor bioclogging at the reservoir). In this study, we created a realistic reservoir model from a heterogeneous gas reservoir in the Southern and phase changes can be attributed to porosity reduction. Our studies suggest that the IP signals provide

  6. Induced Microearthquake Patterns in Hydrocarbon and Geothermal Reservoirs: W. Scott Phillips

    E-Print Network [OSTI]

    Induced Microearthquake Patterns in Hydrocarbon and Geothermal Reservoirs: A Review W. Scott or production of fluids can induce microseismic events in hydrocarbon and geothermal reservoirs. By deploying Patterns in Reservoirs Key Words: induced microseismicity, geothermal, oil and gas, fluid flow, location

  7. Application of horizontal wells in steeply dipping reservoirs 

    E-Print Network [OSTI]

    Lopez Navarro, Jose David

    1995-01-01

    and the anisotropy of permeability (kv/kh ratio) are the dominant parameters affecting the oil recovery. For thin reservoirs, the location of the horizontal injector will not significantly affect the oil recovery. Simultaneous gas and water injection through...

  8. The Role of Acidizing in Proppant Fracturing in Carbonate Reservoirs 

    E-Print Network [OSTI]

    Densirimongkol, Jurairat

    2010-10-12

    Today, optimizing well stimulation techniques to obtain maximum return of investment is still a challenge. Hydraulic fracturing is a typical application to improve ultimate recovery from oil and gas reservoirs. Proppant fracturing has become one...

  9. Simulation of paraffin damage due to natural cooling in reservoirs 

    E-Print Network [OSTI]

    Peddibhotla, Sriram

    1993-01-01

    in the reservoir. Suitable modifications were made to model the paraffin precipitation due to natural cooling. The mechanisms which were modeled include (1) reduction in paraffin solubility due to evolution of dissolved gas and due to temperature changes, (2... independently, after which they were incorporated into a reservoir simulator. Then cases were run to simulate field conditions. Natural cooling is the temperature drop due to the gas leaving solution. The simulation results indicate that natural cooling...

  10. Rate-decline Relations for Unconventional Reservoirs and Development of Parametric Correlations for Estimation of Reservoir Properties 

    E-Print Network [OSTI]

    Askabe, Yohanes 1985-

    2012-10-24

    Time-rate analysis and time-rate-pressure analysis methods are available to estimate reserves and study flow performance of wells in unconventional gas reservoirs. However, these tools are often incorrectly used or the analysis can become difficult...

  11. Relation between facies, diagenesis, and reservoir quality of Rotliegende reservoirs in north Germany

    SciTech Connect (OSTI)

    David, F.; Gast, R.; Kraft, T. (BEB Erdgas Erdol GmbH, Hannover (Germany))

    1993-09-01

    In north Germany, the majority of Rotliegende gas fields is confined to an approximately 50 km-wide east-west-orientated belt, which is situated on the gently north-dipping flank of the southern Permian basin. Approximately 400 billion m[sup 3] of natural gas has been found in Rotliegende reservoir sandstones with average porosities of depths ranging from 3500 to 5000 m. Rotliegende deposition was controlled by the Autunian paleo-relief, and arid climate and cyclic transgressions of the desert lake. In general, wadis and large dunefields occur in the hinterland, sebkhas with small isolate dunes and shorelines define the coastal area, and a desert lake occurs to the north. The sandstones deposited in large dunefields contain only minor amounts of illite, anhydrite, and calcite and form good reservoirs. In contrast, the small dunes formed in the sebkha areas were affected by fluctuations of the desert lake groundwaters, causing the infiltration of detrital clay and precipitation of gypsum and calcite. These cements were transformed to illite, anhydrite, and calcite-II during later diagenesis, leading to a significant reduction of the reservoir quality. The best reservoirs occur in the shoreline sandstones because porosity and permeability were preserved by early magnesium-chlorite diagenesis. Since facies controls diagenesis and consequently reservoir quality, mapping of facies also indicates the distribution of reservoir and nonreservoir rocks. This information is used to identify play area and to interpret and calibrate three-dimensional seismic data.

  12. Reservoir Operation in Texas 

    E-Print Network [OSTI]

    Wurbs, Ralph A.

    1985-01-01

    to store and to release or withdraw for flood control and various conservation purposes. The report is intended to provide a comprehensive, indepth description of how reservoirs are operated in Texas...

  13. The Use of Horizontal Wells in Gas Production from Hydrate Accumulations

    E-Print Network [OSTI]

    Moridis, George J.

    2008-01-01

    saturation V G Cumulative volume of free gas in reservoir [reservoir (m) t Time (s) T Temperature [ o C] Aqueous phase saturation

  14. Integrated reservoir study of the 8 reservoir of the Green Canyon 18 field 

    E-Print Network [OSTI]

    Aniekwena, Anthony Udegbunam

    2004-11-15

    ?????????????????????????... 20 Permeability Determination ???????????????????. 22 Relative Permeability and Capillary Pressure Data ?????????????.? 23 PVT Data ??????????????????????????????. 25 Production and Pressure History Data ???????????????????. 26... ???????????.??. 24 5. Key PVT parameters used ??????????????????????????.??. 25 6. Summary of production forecasts under four different development scenarios ?????.??? 56 7. Reservoir data sheet ???????????????????????????????.. 57 8. Gas...

  15. GEOTHERMAL RESERVOIR SIMULATIONS WITH SHAFT79

    E-Print Network [OSTI]

    Pruess, Karsten

    2012-01-01

    that well blocks must geothermal reservoir s·tudies, paperof Califomia. LBL-10066 GEOTHERMAL RESERVOIR SIMULATIONSbe presented at the Fifth Geothermal Reservoir Engineering

  16. A reservoir management strategy for multilayered reservoirs in eastern Venezuela 

    E-Print Network [OSTI]

    Espinel Diaz, Arnaldo Leopoldo

    1998-01-01

    A reservoir management strategy has been developed for a field located in eastern Venezuela. The field contains deep, high pressure, multilayer reservoirs. A thorough formation evaluation was accomplished using the log data, core data, PVT data...

  17. Experimental production characteristics of anticlinal reservoirs 

    E-Print Network [OSTI]

    Williams, Charles David

    1959-01-01

    field examples showing the importance of gxavity dxain- age on oil reservoir, perfoxmance have been pubhshed. Among these are the Gook Ranch Field in Shackleford County, Texas, the Mile (5) Six Pool in Peru, the Elk Basin Tensleep Reservoiz in Wyom... through the kerosene until a pressure above the desired bubble point pressure was attained. Kerosene was then circulated through. the gas cap in the mixing cylinder with a Hills-McGanna proportlosing pump until no further pressure drop was noted...

  18. Hydrocarbon Reservoir Parameter Estimation Using

    E-Print Network [OSTI]

    van Vliet, Lucas J.

    Hydrocarbon Reservoir Parameter Estimation Using Production Data and Time-Lapse Seismic #12;#12;Hydrocarbon Reservoir Parameter Estimation Using Production Data and Time-Lapse Seismic PROEFSCHRIFT ter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 1.2 Recovery process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 1.3 Field

  19. JOHN W. SNEDDEN RESEARCH INTERESTS: Sequence Stratigraphy, sedimentology, reservoir development

    E-Print Network [OSTI]

    Yang, Zong-Liang

    , Shale Gas, Light Tight Oil). CERTIFIED PETROLEUM GEOLOGIST #5279 AWARDS AND KEY PROFESSIONAL SOCIETY/6, p. 1099-1109. Snedden, J.W., and D.G. Kersey, 1982, Depositional environments and gas production stratigraphic model, 1Y1 Reservoir, Biafra Member, Oso Field, Nigeria: Nigerian Association of Petroleum

  20. Shale Oil Production Performance from a Stimulated Reservoir Volume 

    E-Print Network [OSTI]

    Chaudhary, Anish Singh

    2011-10-21

    RF Recovery factor at 30 years, percent So Oil saturation, fraction Sorg Residual oil saturation at connate gas saturation, fraction Sgc Critical gas saturation, fraction Sw Water saturation, fraction viii SRV Stimulated reservoir volume PVT.................... 24 Table 3: PVT properties of oil used for Eagle Ford oil window well setup .................... 24 Table 4: Relative permeability end points for fracture and matrix.................................. 25...

  1. Research program on fractured petroleum reservoirs. Fourth quarterly report, October 1--December 31, 1993

    SciTech Connect (OSTI)

    Firoozabadi, A.

    1993-01-31

    Progress reports are presented for project 2-supersaturation, critical saturation and residual gas saturation in porous media and for project 5-simulation of fractured reservoirs. Under project 2, a visual high-pressure core-holder has been designed and constructed to be used in critical gas saturation and some other measurements. The apparatus has been used to measure critical gas saturation for a low viscosity mixture. These measurements reconfirm the investigators` previously published data that critical gas saturation for low viscosity fluids are low-around 1 percent. The apparatus is being currently used to measure critical gas saturation of an 11 API oil. Unlike light oils, heavy oil reservoirs, especially fractured heavy oil reservoirs might have an extremely high recovery efficiency with solution gas-drive. The critical gas saturation is an important element of recovery efficiency for such reservoirs.

  2. Applying reservoir characterization technology

    SciTech Connect (OSTI)

    Lake, L.W.

    1994-12-31

    While reservoir characterization is an old discipline, only within the last 10 years have engineers and scientists been able to make quantitative descriptions, due mostly to improvements in high-resolution computational power, sophisticated graphics, and geostatistics. This paper summarizes what has been learned during the past decade by using these technologies.

  3. Reinjection into geothermal reservoirs

    SciTech Connect (OSTI)

    Bodvarsson, G.S.; Stefansson, V.

    1987-08-01

    Reinjection of geothermal wastewater is practiced as a means of disposal and for reservoir pressure support. Various aspects of reinjection are discussed, both in terms of theoretical studies as well as specific field examples. The discussion focuses on the major effects of reinjection, including pressure maintenance and chemical and thermal effects. (ACR)

  4. Shale Gas Application in Hydraulic Fracturing Market is likely...

    Open Energy Info (EERE)

    on unconventional reservoirs such as coal bed methane, tight gas, tight oil, shale gas, and shale oil. Over the period of time, hydraulic fracturing technique has found...

  5. Reviving Abandoned Reservoirs with High-Pressure Air Injection: Application in a Fractured and Karsted Dolomite Reservoir

    SciTech Connect (OSTI)

    Robert Loucks; Stephen C. Ruppel; Dembla Dhiraj; Julia Gale; Jon Holder; Jeff Kane; Jon Olson; John A. Jackson; Katherine G. Jackson

    2006-09-30

    Despite declining production rates, existing reservoirs in the United States contain vast volumes of remaining oil that is not being effectively recovered. This oil resource constitutes a huge target for the development and application of modern, cost-effective technologies for producing oil. Chief among the barriers to the recovery of this oil are the high costs of designing and implementing conventional advanced recovery technologies in these mature, in many cases pressure-depleted, reservoirs. An additional, increasingly significant barrier is the lack of vital technical expertise necessary for the application of these technologies. This lack of expertise is especially notable among the small operators and independents that operate many of these mature, yet oil-rich, reservoirs. We addressed these barriers to more effective oil recovery by developing, testing, applying, and documenting an innovative technology that can be used by even the smallest operator to significantly increase the flow of oil from mature U.S. reservoirs. The Bureau of Economic Geology and Goldrus Producing Company assembled a multidisciplinary team of geoscientists and engineers to evaluate the applicability of high-pressure air injection (HPAI) in revitalizing a nearly abandoned carbonate reservoir in the Permian Basin of West Texas. The Permian Basin, the largest oil-bearing basin in North America, contains more than 70 billion barrels of remaining oil in place and is an ideal venue to validate this technology. We have demonstrated the potential of HPAI for oil-recovery improvement in preliminary laboratory tests and a reservoir pilot project. To more completely test the technology, this project emphasized detailed characterization of reservoir properties, which were integrated to access the effectiveness and economics of HPAI. The characterization phase of the project utilized geoscientists and petroleum engineers from the Bureau of Economic Geology and the Department of Petroleum Engineering (both at The University of Texas at Austin) to define the controls on fluid flow in the reservoir as a basis for developing a reservoir model. The successful development of HPAI technology has tremendous potential for increasing the flow of oil from deep carbonate reservoirs in the Permian Basin, a target resource that can be conservatively estimated at more than 1.5 billion barrels. Successful implementation in the field chosen for demonstration, for example, could result in the recovery of more than 34 million barrels of oil that will not otherwise be produced. Geological and petrophysical analysis of available data at Barnhart field reveals the following important observations: (1) the Barnhart Ellenburger reservoir is similar to most other Ellenburger reservoirs in terms of depositional facies, diagenesis, and petrophysical attributes; (2) the reservoir is characterized by low to moderate matrix porosity much like most other Ellenburger reservoirs in the Permian Basin; (3) karst processes (cave formation, infill, and collapse) have substantially altered stratigraphic architecture and reservoir properties; (4) porosity and permeability increase with depth and may be associated with the degree of karst-related diagenesis; (5) tectonic fractures overprint the reservoir, improving overall connectivity; (6) oil-saturation profiles show that the oil-water contact (OWC) is as much as 125 ft lower than previous estimations; (7) production history and trends suggest that this reservoir is very similar to other solution-gas-drive reservoirs in the Permian Basin; and (8) reservoir simulation study showed that the Barnhart reservoir is a good candidate for HPAI and that application of horizontal-well technology can improve ultimate resource recovery from the reservoir.

  6. Coarse scale simulation of tight gas reservoirs 

    E-Print Network [OSTI]

    El-Ahmady, Mohamed Hamed

    2004-09-30

    and in a square drainage area. The case of horizontally fractured well was also discussed. They considered the case of constant rate production. Applicability of the solutions for analyzing pressure- transient test data was illustrated. 7 Cinco-Ley et... infinite fracture conductivity (Gringarten et al.19) approximately. 8 Cinco-Ley et al.24 discussed thoroughly the limitations and advantages of several methods for analyzing pressure-transient data in fractured wells. Their discussion covered all...

  7. Reservoir Outflow (RESOUT) Model 

    E-Print Network [OSTI]

    Purvis, Stuart Travis

    1988-01-01

    rating tables for a comprehensive range of outlet structure types and configurations, simulating a dam breach, routing a hydrograph through the reservoir, and performing drawdown analyses. The thesis describes the basic equations and computational... of Rating Curves Rating Curves for Uncontrolled Ogee Spillways Rating Curves for Uncontrolled Broad-crested Spillways Rating Curves for Spillway Gates Rating Curves for Drop Inlet Spillways Rating Curves for Outlet Works Breach Simulation Storage...

  8. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2003-04-01

    West Carney Field produces from Hunton Formation. All the wells produce oil, water and gas. The main objective of this study is to understand the unique behavior observed in the field. This behavior includes: (1) Decrease in WOR over time; (2) Decrease in GOR at initial stages; (3) High decline rates of oil and gas; and (4) strong hydrodynamic connectivity between wells. This report specifically addresses two issues relevant to our understanding of the West Carney reservoir. By using core and log data as well as fluorescence information, we demonstrate that our hypothesis of how the reservoir is formed is consistent with these observations. Namely, oil migrated in water wet reservoir, over time, oil changed the wettability of some part of the reservoir, oil eventually leaked to upper formations prompting re-introduction of water into reservoir. Because of change in wettability, different pore size distributions responded differently to water influx. This hypothesis is consistent with fluorescence and porosity data, as we explain it in this quarterly report. The second issue deals with how to best calculate connected oil volume in the reservoir. The log data does not necessarily provide us with relevant information regarding oil in place. However, we have developed a new material balance technique to calculate the connected oil volume based on observed pressure and production data. By using the technique to four different fields producing from Hunton formation, we demonstrate that the technique can be successfully applied to calculate the connected oil in place.

  9. GAS EXPLORATION Winter 2006 GasTIPS 5

    E-Print Network [OSTI]

    Rubin, Yoram

    GAS EXPLORATION Winter 2006 · GasTIPS 5 T he prediction of reservoir parameters such as gas or oil, but is particularly challenging in the case of gas exploration. Current seismic imaging technol- ogy cannot accurately discriminate between economic and non-eco- nomic concentrations of gas. This is primarily because

  10. New correlations for dew-point, specific gravity and producing yield for gas condensates 

    E-Print Network [OSTI]

    Ovalle Cortissoz, Adriana Patricia

    2002-01-01

    This work presents four newly developed correlations to estimate dew-point pressure, current specific gravity and producing yield of gas condensate reservoirs. The first correlation may be used to predict the dew-point pressure of the reservoir gas...

  11. Geochemical analysis of reservoir continuity and connectivity, Arab-D and Hanifa Reservoirs, Abqaiq Field, Saudia Arabia

    SciTech Connect (OSTI)

    Mahdi, A.A.; Grover, G. [Saudi Aramco, Dhahran (Saudi Arabia); Hwang, R. [Chevron Petroleum Technology Co., La Habra, CA (United States)] [and others

    1995-08-01

    Organic geochemistry and its integration with geologic and reservoir engineering data is becoming increasingly utilized to assist geologists and petroleum engineers in solving production related problems. In Abqaiq Field of eastern Saudi Arabia, gas chromatographic analysis (FSCOT) of produced oils from the Arab-D and Hanifa reservoirs was used to evaluate vertical and lateral continuity within and between these reservoirs. Bulk and molecular properties of produced Arab-D oils do not vary significantly over the 70 km length and 10 km width of the reservoir. Hanifa oils, however, do reflect two compositionally distinct populations that are hot in lateral communication, compatible with the occurrence of a large oil pool in the southern part of the field, and a separate, and smaller northern accumulation. The Arab-D and underlying Hanifa oil pools are separated by over 450 feet of impermeable carbonates of the Jubaila Formation, yet the Southern Hanifa pool and the Arab-D have been in pressure communication since onset of Hanifa production in 1954. Recent borehole imaging and core data from horizontal Hanifa wells confirmed the long suspected occurrence of fractures responsible for fluid transmissibility within the porous (up to 35%) but tight (<10md matrix K) Hanifa reservoir, and between the Hanifa and Arab-D. The nearly identical hydrocarbon composition of oils from the Arab-D and southern Hanifa pool provided the final confirmation of fluid communication between the two reservoirs, and extension of a Hanifa fracture-fault network via the Jubaila Formation. This work lead to acquisition of 3-D seismic to image and map the fracture-fault system. The molecular fingerprinting approach demonstrated that produced oils can be used to evaluate vertical and lateral reservoir continuity, and at Abqaiq Field confirmed, in part, the need to produce the Hanifa reservoir via horizontal wells to arrest the reservoir communication that occurs with existing vertical wells.

  12. All-optical Reservoir Computing

    E-Print Network [OSTI]

    Duport, François; Smerieri, Anteo; Haelterman, Marc; Massar, Serge

    2012-01-01

    Reservoir Computing is a novel computing paradigm which uses a nonlinear recurrent dynamical system to carry out information processing. Recent electronic and optoelectronic Reservoir Computers based on an architecture with a single nonlinear node and a delay loop have shown performance on standardized tasks comparable to state-of-the-art digital implementations. Here we report an all-optical implementation of a Reservoir Computer, made of off-the-shelf components for optical telecommunications. It uses the saturation of a semiconductor optical amplifier as nonlinearity. The present work shows that, within the Reservoir Computing paradigm, all-optical computing with state-of-the-art performance is possible.

  13. Author's personal copy Model-based control of multiphase flow in subsurface oil reservoirs

    E-Print Network [OSTI]

    Van den Hof, Paul

    of meters. They are typically in the order of tens of meters thick and cover sev- eral square kilometers this primary recovery phase ends, and it will be necessary to inject water or gas into the reservoir in the oil industry under various names, such as `smart fields', `intelligent fields', `real-time reservoir

  14. Documenting Visual Quality Controls on the Evaluation of Petroleum Reservoir-rocks through

    E-Print Network [OSTI]

    Oliveira, Manuel M.

    , natural gas or water ­ and their permeability ­ the amount of such fluids that can flow through a rockDocumenting Visual Quality Controls on the Evaluation of Petroleum Reservoir-rocks through Ontology and prediction of the quality (porosity, permeability) of petroleum reservoirs during their exploration

  15. Induced Microearthquake Patterns in Hydrocarbon and Geothermal Reservoirs W. Scott Phillips

    E-Print Network [OSTI]

    Induced Microearthquake Patterns in Hydrocarbon and Geothermal Reservoirs W. Scott Phillips James T microseismic events in hydrocarbon and geothermal reservoirs. By deploying sensors downhole, data sets have Key Words: induced microseismicity, geothermal, oil and gas, fluid flow, location #12;2 Introduction

  16. Discrete Fracture Reservoir Simulation

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantityBonneville Power Administration would like submit theCovalentLaboratory | National NuclearDiscoveringDiscrete Fracture Reservoir

  17. Natural and industrial analogues for release of CO2 from storage reservoirs: Identification of features, events, and processes and lessons learned

    E-Print Network [OSTI]

    Lewicki, Jennifer L.; Birkholzer, Jens; Tsang, Chin-Fu

    2006-01-01

    41 2.3.7. Leroy Gas Storage Facility, Wyoming,and M.R. Tek, Leroy gas storage facility, Unita County,reservoirs and natural gas storage facilities, respectively,

  18. Effect of pressure-dependent permeability on tight gas wells 

    E-Print Network [OSTI]

    Franquet Barbara, Mariela

    2005-08-29

    Tight gas reservoirs are those reservoirs where the matrix has a low permeability range (k < 0.1 md). The literature documents laboratory experiments under restressed conditions that show stress dependent rock properties are more significant...

  19. Simple multistage closed-(box+reservoir) models of chemical evolution: an application to the inner Galactic halo

    E-Print Network [OSTI]

    Caimmi, R

    2010-01-01

    Simple closed-box (CB) models of chemical evolution are extended on two respects: (i) simple closed-(box+reservoir) (CBR) models allowing gas outflow from the box into the reservoir or gas inflow into the box from the reservoir with same composition as the preexisting gas and rate proportional to the star formation rate, and (ii) simple multistage closed-(box+reservoir) (MCBR) models allowing different stages of evolution characterized by different inflow or outflow rates. The stellar initial mass function is assumed to be universal, and mass conservation holds for the whole system (box+reservoir) while it is violated for each subsystem (box and reservoir). The theoretical differential oxygen abundance distribution (TDOD) predicted by the model, under the assumption of instantaneous recycling, is a continuous broken line, where different slopes are related to different inflow rates. For an application of the model (a) a fictitious sample is built up from two distinct samples and taken as representative of the...

  20. 120 GRC BULLETIN Reservoir Engineering

    E-Print Network [OSTI]

    Foulger, G. R.

    of The Geysers geothermal area. The production area is shaded grey. Red dots: seismometers with vertical sensors120 GRC BULLETIN Reservoir Engineering nergy production at geothermal areas causes physical changes Tool Use of Time-Dependent MEQ Tomography for Monitoring Producing Geothermal Reservoirs G. R. Foulger

  1. Water resources review: Ocoee reservoirs, 1990

    SciTech Connect (OSTI)

    Cox, J.P.

    1990-08-01

    Tennessee Valley Authority (TVA) is preparing a series of reports to make technical information on individual TVA reservoirs readily accessible. These reports provide a summary of reservoir purpose and operation; physical characteristics of the reservoir and watershed; water quality conditions; aquatic biological conditions; and designated, actual and potential uses of the reservoir and impairments of those use. This reservoir status report addressed the three Ocoee Reservoirs in Polk County, Tennessee.

  2. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2005-02-01

    Hunton formation in Oklahoma has displayed some unique production characteristics. These include high initial water-oil and gas-oil ratios, decline in those ratios over time and temporary increase in gas-oil ratio during pressure build up. The formation also displays highly complex geology, but surprising hydrodynamic continuity. This report addresses three key issues related specifically to West Carney Hunton field and, in general, to any other Hunton formation exhibiting similar behavior: (1) What is the primary mechanism by which oil and gas is produced from the field? (2) How can the knowledge gained from studying the existing fields can be extended to other fields which have the potential to produce? (3) What can be done to improve the performance of this reservoir? We have developed a comprehensive model to explain the behavior of the reservoir. By using available production, geological, core and log data, we are able to develop a reservoir model which explains the production behavior in the reservoir. Using easily available information, such as log data, we have established the parameters needed for a field to be economically successful. We provide guidelines in terms of what to look for in a new field and how to develop it. Finally, through laboratory experiments, we show that surfactants can be used to improve the hydrocarbons recovery from the field. In addition, injection of CO{sub 2} or natural gas also will help us recover additional oil from the field.

  3. Why perform time-lapse seismic monitoring? Is it to ver-ify the reservoir model? No! We should conduct time-lapse

    E-Print Network [OSTI]

    - ued "brightening" of this class III AVO reservoir with pro- duction as the gas saturation continuouslyWhy perform time-lapse seismic monitoring? Is it to ver- ify the reservoir model? No! We should conduct time-lapse seismic surveys in order to find out what is incorrect in the reservoir model, in a way

  4. Completion methods in thick, multilayered tight gas sands 

    E-Print Network [OSTI]

    Ogueri, Obinna Stavely

    2009-05-15

    Tight gas sands, coal-bed methane, and gas shales are commonly called unconventional reservoirs. Tight gas sands (TGS) are often described as formations with an expected average permeability of 0.1mD or less. Gas production rates from TGS reservoirs...

  5. Application of Surrogate Reservoir Model (SRM) to an Onshore Green Field in Saudi Arabia; Case Study

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    at the North Africa Technical Conference and Exhibition held in Cairo, Egypt, 20­22 February 2012. This paper (KPIs) that rank the influence of different reservoir characteristics on the oil and gas production

  6. Rock Physics-Based Carbonate Reservoir Pore Type Evaluation by Combining Geological, Petrophysical and Seismic Data 

    E-Print Network [OSTI]

    Dou, Qifeng

    2012-07-16

    Pore type variations account for complex velocity-porosity relationship and intensive permeability heterogeneity and consequently low oil and gas recovery in carbonate reservoir. However, it is a challenge for geologist ...

  7. Modeling and Analysis of Reservoir Response to Stimulation by Water Injection 

    E-Print Network [OSTI]

    Ge, Jun

    2011-02-22

    The distributions of pore pressure and stresses around a fracture are of interest in conventional hydraulic fracturing operations, fracturing during water-flooding of petroleum reservoirs, shale gas, and injection/extraction operations in a...

  8. Well Performance Analysis for Low to Ultra-low Permeability Reservoir Systems 

    E-Print Network [OSTI]

    Ilk, Dilhan

    2010-10-12

    Unconventional reservoir systems can best be described as petroleum (oil and/or gas) accumulations which are difficult to be characterized and produced by conventional technologies. In this work we present the development of a systematic procedure...

  9. ANALYSIS OF PRODUCTION DECLINE IN GEOTHERMAL RESERVOIRS

    E-Print Network [OSTI]

    Zais, E.J.; Bodvarsson, G.

    2008-01-01

    Petroleum Reservoirs. Geothermal Reservoirs IV. DATA1970, Superheating of Geothermal Steam, Proc. of the U.N.the Development & Utilization of Geothermal Resources, Pisa.

  10. Modeling of Geothermal Reservoirs: Fundamental Processes, Computer...

    Open Energy Info (EERE)

    Abstract This article attempts to critically evaluate the present state of the art of geothermal reservoir simulation. Methodological aspects of geothermal reservoir...

  11. Hydrological and Geochemical Investigations of Selenium Behavior at Kesterson Reservoir

    E-Print Network [OSTI]

    Zawislanski, P.T.

    2010-01-01

    Ecological Characterization of Kesterson Reservoir. AnnualEcological Characterization of Kesterson Reservoir. Annual

  12. Comprehensive Analysis of Enhanced CBM Production via CO2 Injection Using a Surrogate Reservoir Model Jalal Jalali, Shahab D. Mohaghegh, Dept. of Petroleum & Natural Gas Engineering, West Virginia University

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    Model Jalal Jalali, Shahab D. Mohaghegh, Dept. of Petroleum & Natural Gas Engineering, West Virginia

  13. Modeling, History Matching, Forecasting and Analysis of Shale Reservoirs Performance Using Artificial Intelligence

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    matching, forecasting and analyzing oil and gas production in shale reservoirs. In this new approach and analysis of oil and gas production from shale formations. Examples of three case studies in Lower Huron and New Albany shale formations (gas producing) and Bakken Shale (oil producing) is presented

  14. Rock Physics Based Determination of Reservoir Microstructure for Reservoir Characterization 

    E-Print Network [OSTI]

    Adesokan, Hamid 1976-

    2013-01-09

    of pore shape distribution is needed to explain the often-encountered complex interrelationship between seismic parameters (e.g. seismic velocity) and the independent physical properties (e.g. porosity) of hydrocarbon reservoirs. However, our knowledge...

  15. Microsoft Word - NETL-TRS-4-2014_CO2 Storage and Enhanced Gas...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Investigation of CO 2 Storage and Enhanced Gas Recovery in Depleted Shale Gas Formations Using a Dual- PorosityDual-Permeability, Multiphase Reservoir Simulator 25 September 2014...

  16. ANNOTATED RESEARCH BIBLIOGRAPHY FOR GEOTHERMAL RESERVOIR ENGINEERING

    E-Print Network [OSTI]

    Sudo!, G.A

    2012-01-01

    reservoir engineering research program a t the University of Colorado is described. Physical characterization

  17. Toward Production From Gas Hydrates: Current Status, Assessment of Resources, and Simulation-Based Evaluation of Technology and Potential

    E-Print Network [OSTI]

    Moridis, George J.

    2008-01-01

    oil and gas reservoirs, or even to the large (and rapidly increasing) data-base of information on unconventional

  18. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2004-10-01

    West Carney field--one of the newest fields discovered in Oklahoma--exhibits many unique production characteristics. These characteristics include: (1) decreasing water-oil ratio; (2) decreasing gas-oil ratio followed by an increase; (3) poor prediction capability of the reserves based on the log data; and (4) low geological connectivity but high hydrodynamic connectivity. The purpose of this investigation is to understand the principal mechanisms affecting the production, and propose methods by which we can extend the phenomenon to other fields with similar characteristics. In our experimental investigation section, we present the data on surfactant injection in near well bore region. We demonstrate that by injecting the surfactant, the relative permeability of water could be decreased, and that of gas could be increased. This should result in improved gas recovery from the reservoir. Our geological analysis of the reservoir develops the detailed stratigraphic description of the reservoir. Two new stratigraphic units, previously unrecognized, are identified. Additional lithofacies are recognized in new core descriptions. Our engineering analysis has determined that well density is an important parameter in optimally producing Hunton reservoirs. It appears that 160 acre is an optimal spacing. The reservoir pressure appears to decline over time; however, recovery per well is only weakly influenced by the pressure. This indicates that additional opportunity to drill wells exists in relatively depleted fields. A simple material balance technique is developed to validate the recovery of gas, oil and water. This technique can be used to further extrapolate recoveries from other fields with similar field characteristics.

  19. The Basics of Underground Natural Gas Storage

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    Two of the most important characteristics of an underground storage reservoir are its capacity to hold natural gas for future use and the rate at which gas inventory can be...

  20. Production Trends of Shale Gas Wells 

    E-Print Network [OSTI]

    Khan, Waqar A.

    2010-01-14

    To obtain better well performance and improved production from shale gas reservoirs, it is important to understand the behavior of shale gas wells and to identify different flow regions in them over a period of time. It is also important...

  1. Reservoir characterization using wavelet transforms 

    E-Print Network [OSTI]

    Rivera Vega, Nestor

    2004-09-30

    Automated detection of geological boundaries and determination of cyclic events controlling deposition can facilitate stratigraphic analysis and reservoir characterization. This study applies the wavelet transformation, a recent advance in signal...

  2. New developments in high resolution borehole seismology and their applications to reservoir development and management

    SciTech Connect (OSTI)

    Paulsson, B.N.P.

    1997-08-01

    Single-well seismology, Reverse Vertical Seismic Profiles (VSP`s) and Crosswell seismology are three new seismic techniques that we jointly refer to as borehole seismology. Borehole seismic techniques are of great interest because they can obtain much higher resolution images of oil and gas reservoirs than what is obtainable with currently used seismic techniques. The quality of oil and gas reservoir management decisions depend on the knowledge of both the large and the fine scale features in the reservoirs. Borehole seismology is capable of mapping reservoirs with an order of magnitude improvement in resolution compared with currently used technology. In borehole seismology we use a high frequency seismic source in an oil or gas well and record the signal in the same well, in other wells, or on the surface of the earth.

  3. Chickamauga reservoir embayment study - 1990

    SciTech Connect (OSTI)

    Meinert, D.L.; Butkus, S.R.; McDonough, T.A.

    1992-12-01

    The objectives of this report are three-fold: (1) assess physical, chemical, and biological conditions in the major embayments of Chickamauga Reservoir; (2) compare water quality and biological conditions of embayments with main river locations; and (3) identify any water quality concerns in the study embayments that may warrant further investigation and/or management actions. Embayments are important areas of reservoirs to be considered when assessments are made to support water quality management plans. In general, embayments, because of their smaller size (water surface areas usually less than 1000 acres), shallower morphometry (average depth usually less than 10 feet), and longer detention times (frequently a month or more), exhibit more extreme responses to pollutant loadings and changes in land use than the main river region of the reservoir. Consequently, embayments are often at greater risk of water quality impairments (e.g. nutrient enrichment, filling and siltation, excessive growths of aquatic plants, algal blooms, low dissolved oxygen concentrations, bacteriological contamination, etc.). Much of the secondary beneficial use of reservoirs occurs in embayments (viz. marinas, recreation areas, parks and beaches, residential development, etc.). Typically embayments comprise less than 20 percent of the surface area of a reservoir, but they often receive 50 percent or more of the water-oriented recreational use of the reservoir. This intensive recreational use creates a potential for adverse use impacts if poor water quality and aquatic conditions exist in an embayment.

  4. Reservoir characterization of Pennsylvanian Sandstone Reservoirs. Annual report

    SciTech Connect (OSTI)

    Kelkar, M.

    1992-09-01

    This annual report describes the progress during the second year of a project on Reservoir Characterization of Pennsylvanian Sandstone Reservoirs. The report is divided into three sections: (i) reservoir description and scale-up procedures; (ii) outcrop investigation; (iii) in-fill drilling potential. The first section describes the methods by which a reservoir can be characterized, can be described in three dimensions, and can be scaled up with respect to its properties, appropriate for simulation purposes. The second section describes the progress on investigation of an outcrop. The outcrop is an analog of Bartlesville Sandstone. We have drilled ten wells behind the outcrop and collected extensive log and core data. The cores have been slabbed, photographed and the several plugs have been taken. In addition, minipermeameter is used to measure permeabilities on the core surface at six inch intervals. The plugs have been analyzed for the permeability and porosity values. The variations in property values will be tied to the geological descriptions as well as the subsurface data collected from the Glen Pool field. The third section discusses the application of geostatistical techniques to infer in-fill well locations. The geostatistical technique used is the simulated annealing technique because of its flexibility. One of the important reservoir data is the production data. Use of production data will allow us to define the reservoir continuities, which may in turn, determine the in-fill well locations. The proposed technique allows us to incorporate some of the production data as constraints in the reservoir descriptions. The technique has been validated by comparing the results with numerical simulations.

  5. NATURAL GAS STORAGE ENGINEERING Kashy Aminian

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    fields are partially depleted gas (or oil) fields which have been converted to storage. Where depleted oil and gas reservoir are not available, gas can be stored in water bearing sandstones or aquifersNATURAL GAS STORAGE ENGINEERING Kashy Aminian Petroleum & Natural Gas Engineering, West Virginia

  6. TOP-DOWN MODELING; PRACTICAL, FAST TRACK, RESERVOIR SIMULATION & MODELING FOR SHALE FORMATIONS Shahab D. Mohaghegh1 & Grant Bromhal2

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    development in the oil and gas industry and is being used on some shale formations. BAKKEN SHALE MuchTOP-DOWN MODELING; PRACTICAL, FAST TRACK, RESERVOIR SIMULATION & MODELING FOR SHALE FORMATIONS based on measure data, called Top-Down, Intelligent Reservoir Modeling for the shale formations

  7. STATUS OF GEOTHERMAL RESERVOIR ENGINEERING MANAGEMENT PROGRAM ("GREMP") -DECEMBER, 1979

    E-Print Network [OSTI]

    Howard, J. H.

    2012-01-01

    the characteristics of a geothermal reservoir: Items 2, 6,new data important to geothermal reservoir engineering prac-forecast performance of the geothermal reservoir and bore

  8. Integration of well test analysis into naturally fractured reservoir simulation 

    E-Print Network [OSTI]

    Perez Garcia, Laura Elena

    2006-04-12

    Naturally fractured reservoirs (NFR) represent an important percentage of the worldwide hydrocarbon reserves and production. Reservoir simulation is a fundamental technique in characterizing this type of reservoir. Fracture ...

  9. A STOCHASTIC METHOD FOR MODELING FLUID DISPLACEMENT IN PETROLEUM RESERVOIRS

    E-Print Network [OSTI]

    Anderson, C.

    2011-01-01

    FLUID DISPLACEMENT IN PETROLEUM RESERVOIRS C. Anderson andFLUID DISPLACEMENT IN PETROLEUM RESERVOIRS C. Anderson andachieve optimal recovery of petroleum from a reservoir, it

  10. THMC Modeling of EGS Reservoirs ? Continuum through Discontinuum...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    THMC Modeling of EGS Reservoirs Continuum through Discontinuum Representations: Capturing Reservoir Stimulation, Evolution and Induced Seismicity THMC Modeling of EGS Reservoirs...

  11. Atlas of major Appalachian basin gas plays

    SciTech Connect (OSTI)

    Aminian, K.; Avary, K.L.; Baranoski, M.T.; Flaherty, K.; Humphreys, M.; Smosna, R.A.

    1995-06-01

    This regional study of gas reservoirs in the Appalachian basin has four main objectives: to organize all of the -as reservoirs in the Appalachian basin into unique plays based on common age, lithology, trap type and other geologic similarities; to write, illustrate and publish an atlas of major gas plays; to prepare and submit a digital data base of geologic, engineering and reservoir parameters for each gas field; and technology transfer to the oil and gas industry during the preparation of the atlas and data base.

  12. Alleviation of effective permeability reduction of gas-condensate due to condensate buildup near wellbore 

    E-Print Network [OSTI]

    Carballo Salas, Jose Gilberto

    2006-04-12

    When the reservoir pressure is decreased below dew point pressure of the gas near the wellbore, gas-condensate wells start to decrease production because condensate is separated from the gas around the wellbore causing a decrease in gas relative...

  13. UONPR No. 1 Elk Hills: 26R reservoir: Reservoir analysis, reserves and economics, and alternative exploitation strategies: Final technical report

    SciTech Connect (OSTI)

    Not Available

    1989-01-12

    The 26R Stevens Reservoir is located along the southern, west-central flank of the Elk Hills structure in western Kern County, California. In September 1988, the 26R Reservoir produced an average of 22,447 barrels of oil per day from 46 producing wells. The average producing gas-oil ratio was 5912 cubic feet per barrel and the average water cut was 8.4%. The 26R Reservoir was put on production in July 1976, and gas injection for the purpose of pressure maintenance was initiated soon thereafter in October 1976. In September 1988, injection was an average of 168,911 Mcf/D into nine wells, which was in keeping with the policy of injecting 110% of calculated withdrawals. Gas production and residue gas injection are at or near current plant capacity. The purpose of this report is, therefore, to determine if current policy of full pressure maintenance is still viable, or if there is another exploitation option which would better result in maximizing both recovery of hydrocarbons and economic return. 16 figs., 18 tabs.

  14. Gas Production From a Cold, Stratigraphically Bounded Hydrate Deposit at the Mount Elbert Site, North Slope, Alaska

    E-Print Network [OSTI]

    Moridis, G.J.

    2010-01-01

    Mallik 2002 Gas Hydrate Production Research Well Program,Of Methane Hydrate Production Methods To Reservoirs WithNumerical Studies of Gas Production From Methane Hydrates,

  15. Depositional environments, lithofacies types, and reservoir development of the Permian Khuff Formation in Eastern Saudi Arabia

    SciTech Connect (OSTI)

    Al-Jallal, I.A. (Saudi Aramco, Dhahran (Saudi Arabia))

    1991-08-01

    The Later Permian carbonates and evaporites of the Khuff Formation contain considerable amounts of gas in Ghawar field, eastern Saudi Arabia. Sedimentary structures, textures, and grain types were used to interpret the depositional environments and to define the different lithofacies types which determine the original reservoir face is distribution within this 1,500-ft-thick formation. There are three major depositional environments: subtidal, intertidal, and sabkha. Locally, these include shoals, belts, bars, bays, lagoons, ponds, tidal channels, sabkha. Locally, these include shoals, belts, bars, bays, lagoons, ponds, tidal channels, sabkha islands, and sabkha pans. Tidal flooding and storms are represented. These environments represent four major transgressive-regressive cycles, which conform to four Khuff units: Khuff A, B, C and D (from youngest to oldest). Transgressive phases (subtidal), with lithofacies of grainstones and horizontally burrowed mudstones usually comprise the reservoir facies. The regressive phases (intertidal and sabkha) with lithofacies of anhydritic mudstones and anhydrites, usually seal the Khuff reservoirs. Later disappearance of reservoir facies are due to deposition or diagenesis. Depositionally, the lateral change in facies may occur, for example, from a non-reservoir anhydrite and mudstone facies to a reservoir grainstone facies, or from a non-reservoir anhydritic mudstones to a reservoir burrowed-mudstone facies. Diagenetically, ooid grainstones may be greatly cemented by anhydrite. A combination of dolomitization and leaching may create intercrystalline porosity in mudstone. Leaching creates poorly connected moldic porosity in grainstones because the resulting calcite cement plugs the interparticle porosity.

  16. Atomic Rydberg Reservoirs for Polar Molecules

    E-Print Network [OSTI]

    Zhao, Bo; Pupillo, Guido; Zoller, Peter

    2011-01-01

    We discuss laser dressed dipolar and Van der Waals interactions between atoms and polar molecules, so that a cold atomic gas with laser admixed Rydberg levels acts as a designed reservoir for both elastic and inelastic collisional processes. The elastic scattering channel is characterized by large elastic scattering cross sections and repulsive shields to protect from close encounter collisions. In addition, we discuss a dissipative (inelastic) collision where a spontaneously emitted photon carries away (kinetic) energy of the collision partners, thus providing a significant energy loss in a single collision. This leads to the scenario of rapid thermalization and cooling of a molecule in the mK down to the \\mu K regime by cold atoms.

  17. Atomic Rydberg Reservoirs for Polar Molecules

    E-Print Network [OSTI]

    Bo Zhao; Alexander Glätzle; Guido Pupillo; Peter Zoller

    2011-12-18

    We discuss laser dressed dipolar and Van der Waals interactions between atoms and polar molecules, so that a cold atomic gas with laser admixed Rydberg levels acts as a designed reservoir for both elastic and inelastic collisional processes. The elastic scattering channel is characterized by large elastic scattering cross sections and repulsive shields to protect from close encounter collisions. In addition, we discuss a dissipative (inelastic) collision where a spontaneously emitted photon carries away (kinetic) energy of the collision partners, thus providing a significant energy loss in a single collision. This leads to the scenario of rapid thermalization and cooling of a molecule in the mK down to the \\mu K regime by cold atoms.

  18. Design and life-cycle considerations for unconventional-reservoir wells

    SciTech Connect (OSTI)

    Miskimins, J.L.

    2009-05-15

    This paper provides an overview of design and life-cycle considerations for certain unconventional-reservoir wells. An overview of unconventional-reservoir definitions is provided. Well design and life-cycle considerations are addressed from three aspects: upfront reservoir development, initial well completion, and well-life and long-term considerations. Upfront-reservoir-development issues discussed include well spacing, well orientation, reservoir stress orientations, and tubular metallurgy. Initial-well-completion issues include maximum treatment pressures and rates, treatment diversion, treatment staging, flowback and cleanup, and dewatering needs. Well-life and long-term discussions include liquid loading, corrosion, refracturing and associated fracture reorientation, and the cost of abandonment. These design considerations are evaluated with case studies for five unconventional-reservoir types: shale gas (Barnett shale), tight gas (Jonah feld), tight oil (Bakken play), coalbed methane (CBM) (San Juan basin), and tight heavy oil (Lost Hills field). In evaluating the life cycle and design of unconventional-reservoir wells, 'one size' does not fit all and valuable knowledge and a shortening of the learning curve can be achieved for new developments by studying similar, more-mature fields.

  19. Optimization of condensing gas drive 

    E-Print Network [OSTI]

    Lofton, Larry Keith

    1977-01-01

    - cal, undersaturated reservoir with gas being injected into the crest and oil being produced from the base of the structure. Fractional oil re- covery at gas breakthrough proved to be less sensitive to changes in oil withdrawal rates as the gas... injection pressure was increased. The validity of the model was established by accurately simulating several low pressure gas drives conducted in the laboratory. Oil recoveries at gas breakthrough using the model compared closely with those recoveries...

  20. Automated Optimization Strategies for Horizontal Wellbore and Hydraulic Fracture Stages Placement in Unconventional Gas Reseroirs 

    E-Print Network [OSTI]

    Plaksina, Tatyana

    2015-05-05

    In the last decades rapid advances in horizontal drilling and hydraulic fracturing technologies ensure production of commercial quantities of natural gas from many unconventional reservoirs. Reservoir management and development strategies for shale...

  1. Seismic modeling of complex stratified reservoirs 

    E-Print Network [OSTI]

    Lai, Hung-Liang

    2009-05-15

    Turbidite reservoirs in deep-water depositional systems, such as the oil fields in the offshore Gulf of Mexico and North Sea, are becoming an important exploration target in the petroleum industry. Accurate seismic reservoir characterization...

  2. Research on improved and enhanced oil recovery in Illinois through reservoir characterization, March 28, 1992--June 28, 1992

    SciTech Connect (OSTI)

    Oltz, D.F.

    1992-09-01

    This project will provide information that can maximize hydrocarbon production, minimize formation damage and stimulate new production in Illinois. Such information includes definition of hydrocarbon resources, characterization of hydrocarbon reservoirs, and the implementation of methods that will improve hydrocarbon extractive technology. Increased understanding of reservoir heterogeneities that affect oil recovery can aid in identifying producible resources. The transfer of technology to industry and the general public is a significant component of the program. The project is designed to examine selected subsurface oil reservoirs in Illinois. Scientists use advanced scientific techniques to gain a better understanding of reservoir components and behavior and address ways of potentially increasing the amount of recoverable oil. Initial production rates for wells in the Illinois Basin commonly decline quite rapidly and as much as 60 percent of the oil in place can be unrecoverable using standard operating procedures. Heterogeneities (geological differences in reservoir make-up) affect a reservoir`s capability to release fluids. By-passed mobile and immobile oil remain in the reservoir. To learn how to get more of the oil out of reservoirs, the ISGS is studying the nature of reservoir rock heterogeneities and their control on the distribution and production of bypassed, mobile oil. Accomplishment for this period are summarized for the following tasks: mapping, cross-sections; subsurface depo-systems; outcrop studies; oil and gas development maps; engineering work; SEM/EDX; and clay minerals.

  3. OPTIMIZING GEO-CELLULAR RESERVOIR MODELING IN A BRAIDED RIVER INCISED VALLEY FILL: POSTLE FIELD, TEXAS COUNTY, OKLAHOMA

    E-Print Network [OSTI]

    , TEXAS COUNTY, OKLAHOMA by Tiffany Dawn Jobe #12;#12;ABSTRACT Reservoir characterization, modeling Field is a mature oil and gas field in Texas County, Oklahoma which produces from Pennsylvanian valley

  4. Analysis of Geothermal Reservoir Stimulation using Geomechanics...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    between micro-seismicity; reservoir flow and geomechanical characteristics. seismicghassmireservoirstimulation.pdf More Documents & Publications Analysis of...

  5. GEOTHERMAL RESERVOIR SIMULATIONS WITH SHAFT79

    E-Print Network [OSTI]

    Pruess, Karsten

    2012-01-01

    Krafla reservoir. Temperature, pressure and vapor saturationreservoirs because i·t does not residual immobile steam saturation

  6. Reservoir-Stimulation Optimization with Operational Monitoring...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Optimization with Operational Monitoring for Creation of Enhanced Geothermal Systems Reservoir-Stimulation Optimization with Operational Monitoring for Creation...

  7. A reservoir management plan

    SciTech Connect (OSTI)

    Allis, R.G.

    1989-06-16

    There are numerous documented cases of extraction of fluids from the ground causing surface subsidence. The cases include groundwater, oil and gas, as well as geothermal fluid withdrawal. A recent comprehensive review of all types of man-induced land subsidence was published by the Geological Survey of America. At the early stages of a geothermal power development project it is standard practice in most countries for an environmental impact report to be required. The possibility of geothermal subsidence has to be addressed, and usually it falls on the geophysicists and/or geologists to make some predictions. The advice given is vital for planning the power plant location and the borefield pipe and drain layout. It is not so much the vertical settlement that occurs with subsidence but the accompanying horizontal ground strains that can do the most damage to any man-made structure.

  8. Asia Pacific oil and gas conference: Proceedings

    SciTech Connect (OSTI)

    NONE

    1994-12-31

    This book is a compilation of conference proceedings on oil and gas development technologies for the Pacific Rim countries. It includes papers on horizontal drilling technologies, reservoir modeling, corrosion protection techniques, pipeline design and flow measurement, and well logging instrumentation. Other papers deal with resource management and reservoir engineering techniques and modeling. Reservoir engineering papers include enhanced recovery and well stimulation techniques as well as optimizing field depletion.

  9. HIGH TEMPERATURE GEOTHERMAL RESERVOIR ENGINEERING

    E-Print Network [OSTI]

    Schroeder, R.C.

    2009-01-01

    on the Cerro P r i e t o Geothermal F i e l d , Mexicali,e C e r r o P r i e t o Geothermal F i e l d , Baja C a l i1979 HIGH TEMPERATURE GEOTHERMAL RESERVOIR ENGINEERING R.

  10. -Injection Technology -Geothermal Reservoir Engineering

    E-Print Network [OSTI]

    Stanford University

    For the Period October 1, 1985 through September 30, 1986 DE-ASO7-84ID12529 Stanford Geothermal Program was initiated in fiscal year 1981. The report covers the period from October 1, 1985 through September 30, 1986SGP-TR-107 - Injection Technology - Geothermal Reservoir Engineering Research at Stanford Principal

  11. Tenth workshop on geothermal reservoir engineering: proceedings

    SciTech Connect (OSTI)

    Not Available

    1985-01-22

    The workshop contains presentations in the following areas: (1) reservoir engineering research; (2) field development; (3) vapor-dominated systems; (4) the Geysers thermal area; (5) well test analysis; (6) production engineering; (7) reservoir evaluation; (8) geochemistry and injection; (9) numerical simulation; and (10) reservoir physics. (ACR)

  12. Analysis of reservoir performance and forecasting for the eastern area of the C-2 Reservoir, Lake Maracaibo, Venezuela 

    E-Print Network [OSTI]

    Urdaneta Anez, Jackeline C

    2001-01-01

    for the entire reservoir that considers the new geological model developed during reservoir description. Furthermore, it provides PDVSA with a powerful tool for planning and reservoir management decisions, especially in the eastern area of the reservoir...

  13. Naturally fractured reservoirs contain a significant amount of the world oil reserves. A number of these reservoirs contain several

    E-Print Network [OSTI]

    Arbogast, Todd

    Summary Naturally fractured reservoirs contain a significant amount of the world oil reserves simulation of naturally fractured reservoirs is one of the most important, challenging, and computationally intensive problems in reservoir engineering. Parallel reservoir simulators developed for naturally fractured

  14. Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management, Class III

    SciTech Connect (OSTI)

    Koerner, Roy; Clarke, Don; Walker, Scott; Phillips, Chris; Nguyen, John; Moos, Dan; Tagbor, Kwasi

    2001-08-07

    This project was intended to increase recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs, transferring technology so that it can be applied in other sections of the Wilmington field and by operators in other slope and basin reservoirs is a primary component of the project.

  15. High potential recovery -- Gas repressurization

    SciTech Connect (OSTI)

    Madden, M.P.

    1998-05-01

    The objective of this project was to demonstrate that small independent oil producers can use existing gas injection technologies, scaled to their operations, to repressurize petroleum reservoirs and increase their economic oil production. This report gives background information for gas repressurization technologies, the results of workshops held to inform small independent producers about gas repressurization, and the results of four gas repressurization field demonstration projects. Much of the material in this report is based on annual reports (BDM-Oklahoma 1995, BDM-Oklahoma 1996, BDM-Oklahoma 1997), a report describing the results of the workshops (Olsen 1995), and the four final reports for the field demonstration projects which are reproduced in the Appendix. This project was designed to demonstrate that repressurization of reservoirs with gas (natural gas, enriched gas, nitrogen, flue gas, or air) can be used by small independent operators in selected reservoirs to increase production and/or decrease premature abandonment of the resource. The project excluded carbon dioxide because of other DOE-sponsored projects that address carbon dioxide processes directly. Two of the demonstration projects, one using flue gas and the other involving natural gas from a deeper coal zone, were both technical and economic successes. The two major lessons learned from the projects are the importance of (1) adequate infrastructure (piping, wells, compressors, etc.) and (2) adequate planning including testing compatibility between injected gases and fluids, and reservoir gases, fluids, and rocks.

  16. Simulation studies to evaluate the effect of fracture closure on the performance of fractured reservoirs; Final report

    SciTech Connect (OSTI)

    Howrie, I.; Dauben, D.

    1994-03-01

    A three-year research program to evaluate the effect of fracture closure on the recovery of oil and gas from naturally fractured reservoirs has been completed. The overall objectives of the study were to: (1) evaluate the reservoir conditions for which fracture closure is significant, and (2) evaluate innovative fluid injection techniques capable of maintaining pressure within the reservoir. The evaluations of reservoir performance were made by a modern dual porosity simulator, TETRAD. This simulator treats both porosity and permeability as functions of pore pressure. The Austin Chalk in the Pearsall Field in of South Texas was selected as the prototype fractured reservoir for this work. During the first year, simulations of vertical and horizontal well performance were made assuming that fracture permeability was insensitive to pressure change. Sensitivity runs indicated that the simulator was predicting the effects of critical reservoir parameters in a logical and consistent manner. The results confirmed that horizontal wells could increase both rate of oil recovery and total oil recovery from naturally fractured reservoirs. In the second year, the performance of the same vertical and horizontal wells was reevaluated with fracture permeability treated as a function of reservoir pressure. To investigate sensitivity to in situ stress, differing loading conditions were assumed. Simulated natural depletions confirm that pressure sensitive fractures degrade well performance. The severity of degradation worsens when the initial reservoir pressure approaches the average stress condition of the reservoir, such as occurs in over pressured reservoirs. Simulations with water injection indicate that degradation of permeability can be counteracted when reservoir pressure is maintained and oil recovery can be increased when reservoir properties are favorable.

  17. The role of reservoir characterization in the reservoir management process (as reflected in the Department of Energy`s reservoir management demonstration program)

    SciTech Connect (OSTI)

    Fowler, M.L.; Young, M.A.; Madden, M.P.

    1997-08-01

    Optimum reservoir recovery and profitability result from guidance of reservoir practices provided by an effective reservoir management plan. Success in developing the best, most appropriate reservoir management plan requires knowledge and consideration of (1) the reservoir system including rocks, and rock-fluid interactions (i.e., a characterization of the reservoir) as well as wellbores and associated equipment and surface facilities; (2) the technologies available to describe, analyze, and exploit the reservoir; and (3) the business environment under which the plan will be developed and implemented. Reservoir characterization is the essential to gain needed knowledge of the reservoir for reservoir management plan building. Reservoir characterization efforts can be appropriately scaled by considering the reservoir management context under which the plan is being built. Reservoir management plans de-optimize with time as technology and the business environment change or as new reservoir information indicates the reservoir characterization models on which the current plan is based are inadequate. BDM-Oklahoma and the Department of Energy have implemented a program of reservoir management demonstrations to encourage operators with limited resources and experience to learn, implement, and disperse sound reservoir management techniques through cooperative research and development projects whose objectives are to develop reservoir management plans. In each of the three projects currently underway, careful attention to reservoir management context assures a reservoir characterization approach that is sufficient, but not in excess of what is necessary, to devise and implement an effective reservoir management plan.

  18. ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM

    SciTech Connect (OSTI)

    Mark B. Murphy

    2004-01-31

    The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

  19. ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM

    SciTech Connect (OSTI)

    Mark B. Murphy

    2002-12-31

    The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

  20. ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM

    SciTech Connect (OSTI)

    Mark B. Murphy

    2003-07-30

    The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

  1. ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM

    SciTech Connect (OSTI)

    Mark B. Murphy

    2003-10-31

    The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

  2. 4. International reservoir characterization technical conference

    SciTech Connect (OSTI)

    1997-04-01

    This volume contains the Proceedings of the Fourth International Reservoir Characterization Technical Conference held March 2-4, 1997 in Houston, Texas. The theme for the conference was Advances in Reservoir Characterization for Effective Reservoir Management. On March 2, 1997, the DOE Class Workshop kicked off with tutorials by Dr. Steve Begg (BP Exploration) and Dr. Ganesh Thakur (Chevron). Tutorial presentations are not included in these Proceedings but may be available from the authors. The conference consisted of the following topics: data acquisition; reservoir modeling; scaling reservoir properties; and managing uncertainty. Selected papers have been processed separately for inclusion in the Energy Science and Technology database.

  3. Fast Track Reservoir Modeling of Shale Formations in the Appalachian Basin. Application to Lower Huron Shale in Eastern Kentucky.

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    Huron Shale - Gas production from Devonian Shale in Eastern Kentucky goes all the way back to 1892, when of the reservoir, efficient gas production was established. The most prolific horizon of Devonian Shale in Eastern Kentucky is the Lower Huron Shale, which is Ohio Shale member. Over 80% of Devonian gas production comes

  4. SEISMIC EVALUATION OF HYDROCARBON SATURATION IN DEEP-WATER RESERVOIRS

    SciTech Connect (OSTI)

    Michael Batzle; D-h Han; R. Gibson; Huw James

    2005-08-12

    We are now entering the final stages of our ''Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs'' project (Grant/Cooperative Agreement DE-FC26-02NT15342). We have now developed several techniques to help distinguish economic hydrocarbon deposits from false ''Fizz'' gas signatures. These methods include using the proper in situ rock and fluid properties, evaluating interference effects on data, and doing better constrained inversions for saturations. We are testing these techniques now on seismic data from several locations in the Gulf of Mexico. In addition, we are examining the use of seismic attenuation as indicated by frequency shifts below potential reservoirs. During this quarter we have: Began our evaluation of our latest data set over the Neptune Field; Developed software for computing composite reflection coefficients; Designed and implemented stochastic turbidite reservoir models; Produced software & work flow to improve frequency-dependent AVO analysis; Developed improved AVO analysis for data with low signal-to-noise ratio; and Examined feasibility of detecting fizz gas using frequency attenuation. Our focus on technology transfer continues, both by generating numerous presentations for the upcoming SEG annual meeting, and by beginning our planning for our next DHI minisymposium next spring.

  5. Research on improved and enhanced oil recovery in Illinois through reservoir characterization, March 28, 1992--June 28, 1992

    SciTech Connect (OSTI)

    Oltz, D.F.

    1992-01-01

    This project will provide information that can maximize hydrocarbon production, minimize formation damage and stimulate new production in Illinois. Such information includes definition of hydrocarbon resources, characterization of hydrocarbon reservoirs, and the implementation of methods that will improve hydrocarbon extractive technology. Increased understanding of reservoir heterogeneities that affect oil recovery can aid in identifying producible resources. The transfer of technology to industry and the general public is a significant component of the program. The project is designed to examine selected subsurface oil reservoirs in Illinois. Scientists use advanced scientific techniques to gain a better understanding of reservoir components and behavior and address ways of potentially increasing the amount of recoverable oil. Initial production rates for wells in the Illinois Basin commonly decline quite rapidly and as much as 60 percent of the oil in place can be unrecoverable using standard operating procedures. Heterogeneities (geological differences in reservoir make-up) affect a reservoir's capability to release fluids. By-passed mobile and immobile oil remain in the reservoir. To learn how to get more of the oil out of reservoirs, the ISGS is studying the nature of reservoir rock heterogeneities and their control on the distribution and production of bypassed, mobile oil. Accomplishment for this period are summarized for the following tasks: mapping, cross-sections; subsurface depo-systems; outcrop studies; oil and gas development maps; engineering work; SEM/EDX; and clay minerals.

  6. Direct estimation of gas reserves using production data 

    E-Print Network [OSTI]

    Buba, Ibrahim Muhammad

    2004-09-30

    This thesis presents the development of a semi-analytical technique that can be used to estimate the gas-in-place for volumetric gas reservoirs. This new methodology utilizes plotting functions, plots, extrapolations, ...

  7. A New Global Unconventional Natural Gas Resource Assessment 

    E-Print Network [OSTI]

    Dong, Zhenzhen

    2012-10-19

    In 1997, Rogner published a paper containing an estimate of the natural gas in place in unconventional reservoirs for 11 world regions. Rogner's work was assessing the unconventional gas resource base, and is now considered to be very conservative...

  8. Producing Light Oil from a Frozen Reservoir: Reservoir and Fluid Characterization of Umiat Field, National Petroleum Reserve, Alaska

    SciTech Connect (OSTI)

    Hanks, Catherine

    2012-12-31

    Umiat oil field is a light oil in a shallow, frozen reservoir in the Brooks Range foothills of northern Alaska with estimated oil-in-place of over 1 billion barrels. Umiat field was discovered in the 1940’s but was never considered viable because it is shallow, in the permafrost, and far from any transportation infrastructure. The advent of modern drilling and production techniques has made Umiat and similar fields in northern Alaska attractive exploration and production targets. Since 2008 UAF has been working with Renaissance Alaska Inc. and, more recently, Linc Energy, to develop a more robust reservoir model that can be combined with rock and fluid property data to simulate potential production techniques. This work will be used to by Linc Energy as they prepare to drill up to 5 horizontal wells during the 2012-2013 drilling season. This new work identified three potential reservoir horizons within the Cretaceous Nanushuk Formation: the Upper and Lower Grandstand sands, and the overlying Ninuluk sand, with the Lower Grandstand considered the primary target. Seals are provided by thick interlayered shales. Reserve estimates for the Lower Grandstand alone range from 739 million barrels to 2437 million barrels, with an average of 1527 million bbls. Reservoir simulations predict that cold gas injection from a wagon-wheel pattern of multilateral injectors and producers located on 5 drill sites on the crest of the structure will yield 12-15% recovery, with actual recovery depending upon the injection pressure used, the actual Kv/Kh encountered, and other geologic factors. Key to understanding the flow behavior of the Umiat reservoir is determining the permeability structure of the sands. Sandstones of the Cretaceous Nanushuk Formation consist of mixed shoreface and deltaic sandstones and mudstones. A core-based study of the sedimentary facies of these sands combined with outcrop observations identified six distinct facies associations with distinctive permeability trends. The Lower Grandstand sand consists of two coarsening-upward shoreface sands sequences while the Upper Grandstand consists of a single coarsening-upward shoreface sand. Each of the shoreface sands shows a distinctive permeability profile with high horizontal permeability at the top getting progressively poorer towards the base of the sand. In contrast, deltaic sandstones in the overlying Ninuluk are more permeable at the base of the sands, with decreasing permeability towards the sand top. These trends impart a strong permeability anisotropy to the reservoir and are being incorporated into the reservoir model. These observations also suggest that horizontal wells should target the upper part of the major sands. Natural fractures may superimpose another permeability pattern on the Umiat reservoir that need to be accounted for in both the simulation and in drilling. Examination of legacy core from Umiat field indicate that fractures are present in the subsurface, but don't provide information on their orientation and density. Nearby surface exposures of folds in similar stratigraphy indicate there are at least three possible fracture sets: an early, N/S striking set that may predate folding and two sets possibly related to folding: an EW striking set of extension fractures that are parallel to the fold axes and a set of conjugate shear fractures oriented NE and NW. Analysis of fracture spacing suggests that these natural fractures are fairly widely spaced (25-59 cm depending upon the fracture set), but could provide improved reservoir permeability in horizontal legs drilled perpendicular to the open fracture set. The phase behavior of the Umiat fluid needed to be well understood in order for the reservoir simulation to be accurate. However, only a small amount of Umiat oil was available; this oil was collected in the 1940’s and was severely weathered. The composition of this ‘dead’ Umiat fluid was characterized by gas chromatography. This analysis was then compared to theoretical Umiat composition derived using the Pedersen method with original Umiat

  9. Storage capacity in hot dry rock reservoirs

    DOE Patents [OSTI]

    Brown, D.W.

    1997-11-11

    A method is described for extracting thermal energy, in a cyclic manner, from geologic strata which may be termed hot dry rock. A reservoir comprised of hot fractured rock is established and water or other liquid is passed through the reservoir. The water is heated by the hot rock, recovered from the reservoir, cooled by extraction of heat by means of heat exchange apparatus on the surface, and then re-injected into the reservoir to be heated again. Water is added to the reservoir by means of an injection well and recovered from the reservoir by means of a production well. Water is continuously provided to the reservoir and continuously withdrawn from the reservoir at two different flow rates, a base rate and a peak rate. Increasing water flow from the base rate to the peak rate is accomplished by rapidly decreasing backpressure at the outlet of the production well in order to meet periodic needs for amounts of thermal energy greater than a baseload amount, such as to generate additional electric power to meet peak demands. The rate of flow of water provided to the hot dry rock reservoir is maintained at a value effective to prevent depletion of the liquid inventory of the reservoir. 4 figs.

  10. Computer Simulation of Reservoir Depletion and Oil Flow from the Macondo Well Following the Deepwater

    E-Print Network [OSTI]

    ................................................................................................................................................... 2 Reservoir Model ............................................................................................................................................. 7 Uncertainty Analysis........................................................................................................................................... 8 Tables Table 1. Reservoir and fluid properties used in the reservoir simulation model

  11. Evaluation and Prediction of Unconventional Gas Resources in Underexplored Basins Worldwide 

    E-Print Network [OSTI]

    Cheng, Kun

    2012-07-16

    As gas production from conventional gas reservoirs in the United States decreases, industry is turning more attention to the exploration and development of unconventional gas resources (UGR). This trend is expanding quickly ...

  12. Olig sand, shallow oil zone, Elk Hills Field, Kern County, California: General reservoir study

    SciTech Connect (OSTI)

    Not Available

    1986-08-01

    The Olig Sand Reservoirs, classified as part of the Shallow Oil Zone, were studied and evaluated. The reservoirs are located in Section 30R, T30S, R23E and Section 24Z, T30S, R22E, M.D.B. and M., all in Elk Hills Oil Field, Naval Petroleum Reserve No. 1, Kern County, California. The three productive reservoirs studied cover an area of 255 acres, and originally contained 3311 MMCF of gas condensate in 4292 acre-feet of sand. The main reservoir, Fault Block I in Section 30R, has been on production since 1982 and is largely depleted. The reservoirs around wells 324-30R and 385-24Z should still be in a virgin state. They can be depleted either through those wells, when their service as Stevens Zone producers is completed, or by twin well replacements drilled specifically as Olig Sand completions. Thirty-six exhibits have been included to present basic data and study results in a manner that will enhance the readers's understanding of the reservoirs. These exhibits include six maps in the M-series, six sections in the S-Series, and fourteen figures in the F-Series, as well as ten tables. The Appendix includes miscellaneous basic data such as well logs, core analyses, pressure measurements, and well tests. The Calculations Section of the report develops and explains the analytical methods used to define well productivity, determine reserves, and schedule future production of those reserves. Although no MER recommendations have been made for these gas condensate reservoirs, recommended depletion schemes and schedules are presented. These schemes include one eventual recompletion and one new well to maximize present worth of these reservoirs which carry proved reserves of 289 MMCF and probable reserves of 853 MMCF, effective August 1, 1986. In addition, potential future testing is earmarked for wells 322-30R and 344-30R. 11 refs., 14 figs., 10 tabs.

  13. Sedimentation in Shallow ReservoirsPoster n 21 Large shallow reservoirs of run-of-river

    E-Print Network [OSTI]

    Dalang, Robert C.

    Sedimentation in Shallow ReservoirsPoster n° 21 Large shallow reservoirs of run-of-river power plants on rivers with high suspended sediments are endangered by significant sedimentation. INTRODUCTION

  14. A better understanding of a Uinta Basin channelized analog reservoir through geostatistics and reservoir simulation 

    E-Print Network [OSTI]

    Robbana, Enis

    2002-01-01

    The Green River Formation is located in the Uinta basin of northeastern Utah. It contains several reservoirs that can be classified as lacustrine such as the Altamont-Bluebell and Red Wash. Lacustrine reservoirs are ...

  15. Analysis of Geothermal Reservoir Stimulation using Geomechanics...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of...

  16. 201202 Reservoir System Modeling Technologies Conference

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Modeling Applied To The Columbia River - PSR Adjoint Modeling Framework for Real-Time Control of Water - Deltares Reservoir Operations Analysis in the Willamette Water 2100...

  17. International reservoir operations agreement helps NW fish &...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    or 503-230-5131 International reservoir operations agreement helps Northwest fish and power Portland, Ore. - The Bonneville Power Administration and the British Columbia...

  18. Storage capacity in hot dry rock reservoirs

    DOE Patents [OSTI]

    Brown, Donald W. (Los Alamos, NM)

    1997-01-01

    A method of extracting thermal energy, in a cyclic manner, from geologic strata which may be termed hot dry rock. A reservoir comprised of hot fractured rock is established and water or other liquid is passed through the reservoir. The water is heated by the hot rock, recovered from the reservoir, cooled by extraction of heat by means of heat exchange apparatus on the surface, and then re-injected into the reservoir to be heated again. Water is added to the reservoir by means of an injection well and recovered from the reservoir by means of a production well. Water is continuously provided to the reservoir and continuously withdrawn from the reservoir at two different flow rates, a base rate and a peak rate. Increasing water flow from the base rate to the peak rate is accomplished by rapidly decreasing backpressure at the outlet of the production well in order to meet periodic needs for amounts of thermal energy greater than a baseload amount, such as to generate additional electric power to meet peak demands. The rate of flow of water provided to the hot dry rock reservoir is maintained at a value effective to prevent depletion of the liquid

  19. Assessing the relative permeability of heterogeneous reservoir...

    Office of Scientific and Technical Information (OSTI)

    susceptible to error and may lead to incorrect conclusions regarding displacement efficiency, wettability and reservoir performance. This paper focuses on new techniques for...

  20. Geothermal reservoirs in hydrothermal convection systems

    SciTech Connect (OSTI)

    Sorey, M.L.

    1982-01-01

    Geothermal reservoirs commonly exist in hydrothermal convection systems involving fluid circulation downward in areas of recharge and upwards in areas of discharge. Because such reservoirs are not isolated from their surroundings, the nature of thermal and hydrologic connections with the rest of the system may have significant effects on the natural state of the reservoir and on its response to development. Conditions observed at numerous developed and undeveloped geothermal fields are discussed with respect to a basic model of the discharge portion of an active hydrothermal convection system. Effects of reservoir development on surficial discharge of thermal fluid are also delineated.

  1. Characterization of geothermal reservoir crack patterns using...

    Open Energy Info (EERE)

    with form History Characterization of geothermal reservoir crack patterns using shear-wave splitting Jump to: navigation, search OpenEI Reference LibraryAdd to library Journal...

  2. Evaluation Of Chemical Geothermometers For Calculating Reservoir...

    Open Energy Info (EERE)

    Evaluation Of Chemical Geothermometers For Calculating Reservoir Temperatures At Nevada Geothermal Power Plants Jump to: navigation, search OpenEI Reference LibraryAdd to library...

  3. SEISMIC ATTENUATION FOR RESERVOIR CHARACTERIZATION

    SciTech Connect (OSTI)

    Joel Walls; M.T. Taner; Gary Mavko; Jack Dvorkin

    2002-04-01

    Wave-induced variations of pore pressure in a partially-saturated reservoir result in oscillatory liquid flow. The viscous losses during this flow are responsible for wave attenuation. The same viscous effects determine the changes in the dynamic bulk modulus of the system versus frequency. These changes are necessarily linked to attenuation via the causality condition. We analytically quantify the frequency dependence of the bulk modulus of a partially saturated rock by assuming that saturation is patchy and then link these changes to the inverse quality factor. As a result, the P-wave attenuation is quantitatively linked to saturation and thus can serve as a saturation indicator.

  4. The verification of a semi-analytical reservoir simulator using a finite difference reservoir simulator 

    E-Print Network [OSTI]

    Dube, Hans Gerhardt

    1990-01-01

    of Cases Fundamental Difference Between the Reservoir Simulators. Data Sets. . General Process of Verification. . . . . . . . . . . . . . . 22 24 25 25 26 29 32 36 SINGLE LAYER, RADIAL FLOW DRAWDOWN CASES. . 38 viii Page Infinite Cylindrical... Drawdown Problems. . . . . . . . . . . . . 38 41 43 45 49 50 52 MULTIPLE LAYER RESERVOIR, RADIAL FLOW DRAWDOWN CASES. 63 Simulation of Multiple Layer Reservoirs. . . . . . Simulation Parameters. Constant Rate Drawdown Tests in an Infinite...

  5. Computed microtomography of reservoir core samples

    SciTech Connect (OSTI)

    Coles, M.E.; Muegge, E.L.; Spanne, P.; Jones, K.W.

    1995-03-01

    X-ray computed tomography (CT) is often utilized to evaluate and characterize structural characteristics within reservoir core material systems. Generally, medical CT scanners have been employed because of their availability and ease of use. Of interest lately has been the acquisition of three-dimensional, high resolution descriptions of rock and pore structures for characterization of the porous media and for modeling of single and multiphase transport processes. The spatial resolution of current medical CT scanners is too coarse for pore level imaging of most core samples. Recently developed high resolution computed microtomography (CMT) using synchrotron X-ray sources is analogous to conventional medical CT scanning and provides the ability to obtain three-dimensional images of specimens with a spatial resolution on the order of micrometers. Application of this technique to the study of core samples provides two- and three-dimensional high resolution description of pore structure and mineral distributions. Pore space and interconnectivity is accurately characterized and visualized. Computed microtomography data can serve as input into pore-level simulation techniques. A generalized explanation of the technique is provided, with comparison to conventional CT scanning techniques and results. Computed microtomographic results of several sandstone samples are presented and discussed. Bulk porosity values and mineralogical identification were obtained from the microtomograms and compared with gas porosity and scanning electron microscope results on tandem samples.

  6. Mapping steam and water flow in petroleum reservoirs

    SciTech Connect (OSTI)

    Wilt, M.; Schenkel, C. [Lawrence Livermore National Lab., CA (United States); Daley, T.; Peterson, J.; Majer, E. [Lawrence Berkeley National Lab., CA (United States); Murer, A.S. [Mobil Exploration and Producing US (United States); Johnston, R.M. [SPE, CalResources LLC (United States); Klonsky, L. [Chevron USA Production Co. (United States)

    1996-11-01

    Over the past 5 years, we have applied high-resolution geophysical methods (crosswell seismic and electromagnetics (EM), and passive seismic) to map and characterize petroleum reservoirs in the San Joaquin Valley and to monitor changes during secondary recovery operations. The two techniques provide complementary information. Seismic data reveal the reservoir structure, whereas EM measurements are more sensitive to the pore fluid distribution. Seismic surveys at the south Belridge field were used to map fracture generation and monitor formation changes due to the onset of steam flooding. Early results show possible sensitivity to changes in gas saturation caused by the steam flooding. Crosswell EM surveys were applied at a shallow pilot at Lost Hills for reservoir characterization and steamflood monitoring. Images made from baselines data clearly show the distribution of the target oil sands; repeated surveys during the steam flood allowed us to identify the boundaries of the steam chest and to accurately predict breakthrough. Applications of the EM techniques in steel-cased wells are at an early stage, but preliminary results at Lost Hills show sensitivity to formation resistivity in a water-flood pilot. Finally, passive seismic surveys during hydrofracture operations measured events corelatable in frequency content and magnitude with the size and orientation of induced fractures.

  7. Geothermal Reservoir Temperatures in Southeastern Idaho using Multicomponent Geothermometry

    SciTech Connect (OSTI)

    Neupane, Ghanashyam; Mattson, Earl D.; McLing, Travis L.; Palmer, Carl D.; Smith, Robert W.; Wood, Thomas R.; Podgorney, Robert K.

    2015-03-01

    Southeastern Idaho exhibits numerous warm springs, warm water from shallow wells, and hot water within oil and gas test wells that indicate a potential for geothermal development in the area. Although the area exhibits several thermal expressions, the measured geothermal gradients vary substantially (19 – 61 ºC/km) within this area, potentially suggesting a redistribution of heat in the overlying ground water from deeper geothermal reservoirs. We have estimated reservoir temperatures from measured water compositions using an inverse modeling technique (Reservoir Temperature Estimator, RTEst) that calculates the temperature at which multiple minerals are simultaneously at equilibrium while explicitly accounting for the possible loss of volatile constituents (e.g., CO2), boiling and/or water mixing. Compositions of a selected group of thermal waters representing southeastern Idaho hot/warm springs and wells were used for the development of temperature estimates. The temperature estimates in the the region varied from moderately warm (59 ºC) to over 175 ºC. Specifically, hot springs near Preston, Idaho resulted in the highest temperature estimates in the region.

  8. Reservoir Characterization Research Laboratory Research Plans for 2013

    E-Print Network [OSTI]

    Texas at Austin, University of

    and Subsurface Characterization of Carbonate Reservoirs for Improved Recovery of Remaining Hydrocarbons Charles#12; Reservoir Characterization Research Laboratory Research Plans for 2013 Outcrop for heavy oil deposits within the Canadian Grosmont Formation. #12;iii Reservoir Characterization Research

  9. Monitoring EGS Stimulation and Reservoir Dynamics with InSAR...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    EGS Stimulation and Reservoir Dynamics with InSAR and MEQ Monitoring EGS Stimulation and Reservoir Dynamics with InSAR and MEQ Monitoring EGS Stimulation and Reservoir Dynamics...

  10. Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Clarke, Don; Koerner, Roy; Moos, Dan; Nguyen, John; Phillips, Chris; Tagbor, Kwasi; Walker, Scott

    1999-11-09

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period July - September 1998 and to report all technical data and findings as specified in the ''Federal Assistance Reporting Checklist''. The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology.

  11. Increasing Waterflood Reserves in the Wilmington Oil Field Through Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Chris Phillips; Dan Moos; Don Clarke; John Nguyen; Kwasi Tagbor; Roy Koerner; Scott Walker

    1997-04-10

    This project is intended to increase recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs. Transferring technology so that it can be applied in other sections of the Wilmington Field and by operators in other slope and basin reservoirs is a primary component of the project.

  12. US crude oil, natural gas, and natural gas liquids reserves

    SciTech Connect (OSTI)

    Not Available

    1990-10-05

    This report presents estimates of proved reserves of crude oil, natural gas, and natural gas liquids as of December 31, 1989, and production volumes for the year 1989 for the total United States and for selected states and state sub-divisions. Estimates are presented for the following four categories of natural gas: total gas (wet after lease separation), its two major components (nonassociated and associated-dissolved gas), and total dry gas (wet gas adjusted for the removal of liquids at natural gas processing plants). In addition, two components of natural gas liquids, lease condensate and natural gas plant liquids, have their reserves and production reported separately. Also included is information on indicated additional crude oil reserves and crude oil, natural gas, and lease condensate reserves in nonproducing reservoirs. 28 refs., 9 figs., 15 tabs.

  13. Geothermal reservoir insurance study. Final report

    SciTech Connect (OSTI)

    Not Available

    1981-10-09

    The principal goal of this study was to provide analysis of and recommendations on the need for and feasibility of a geothermal reservoir insurance program. Five major tasks are reported: perception of risk by major market sectors, status of private sector insurance programs, analysis of reservoir risks, alternative government roles, and recommendations.

  14. GEOMECHANICAL MODELING AS A RESERVOIR CHARACTERIZATION TOOL

    E-Print Network [OSTI]

    GEOMECHANICAL MODELING AS A RESERVOIR CHARACTERIZATION TOOL AT RULISON FIELD, PICEANCE BASIN _______________ ____________________ Dr. Terence K. Young Department Head Department of Geophysics ii #12;ABSTRACT Geomechanics is a powerful reservoir characterization tool. Geomechanical modeling is used here to understand how the in

  15. Water resources review: Wheeler Reservoir, 1990

    SciTech Connect (OSTI)

    Wallus, R.; Cox, J.P.

    1990-09-01

    Protection and enhancement of water quality is essential for attaining the full complement of beneficial uses of TVA reservoirs. The responsibility for improving and protecting TVA reservoir water quality is shared by various federal, state, and local agencies, as well as the thousands of corporations and property owners whose individual decisions affect water quality. TVA's role in this shared responsibility includes collecting and evaluating water resources data, disseminating water resources information, and acting as a catalyst to bring together agencies and individuals that have a responsibility or vested interest in correcting problems that have been identified. This report is one in a series of status reports that will be prepared for each of TVA's reservoirs. The purpose of this status report is to provide an up-to-date overview of the characteristics and conditions of Wheeler Reservoir, including: reservoir purposes and operation; physical characteristics of the reservoir and the watershed; water quality conditions: aquatic biological conditions: designated, actual, and potential uses of the reservoir and impairments of those uses; ongoing or planned reservoir management activities. Information and data presented here are form the most recent reports, publications, and original data available. 21 refs., 8 figs., 29 tabs.

  16. Economics of Developing Hot Stratigraphic Reservoirs

    SciTech Connect (OSTI)

    Greg Mines; Hillary Hanson; Rick Allis; Joseph Moore

    2014-09-01

    Stratigraphic geothermal reservoirs at 3 – 4 km depth in high heat-flow basins are capable of sustaining 100 MW-scale power plants at about 10 c/kWh. This paper examines the impacts on the levelized cost of electricity (LCOE) of reservoir depth and temperature, reservoir productivity, and drillhole/casing options. For a reservoir at 3 km depth with a moderate productivity index by hydrothermal reservoir standards (about 50 L/s/MPa, 5.6 gpm/psi), an LCOE of 10c/kWh requires the reservoir to be at about 200°C. This is the upper temperature limit for pumps. The calculations assume standard hydrothermal drilling costs, with the production interval completed with a 7 inch liner in an 8.5 inch hole. If a reservoir at 4 km depth has excellent permeability characteristics with a productivity index of 100 L/s/MPa (11.3 gpm/psi), then the LCOE is about 11 c/kWh assuming the temperature decline rate with development is not excessive (< 1%/y, with first thermal breakthrough delayed by about 10 years). Completing wells with modest horizontal legs (e.g. several hundred meters) may be important for improving well productivity because of the naturally high, sub-horizontal permeability in this type of reservoir. Reducing the injector/producer well ratio may also be cost-effective if the injectors are drilled as larger holes.

  17. Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs

    SciTech Connect (OSTI)

    Michael Batzle

    2006-04-30

    During this last period of the ''Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs'' project (Grant/Cooperative Agreement DE-FC26-02NT15342), we finalized integration of rock physics, well log analysis, seismic processing, and forward modeling techniques. Most of the last quarter was spent combining the results from the principal investigators and come to some final conclusions about the project. Also much of the effort was directed towards technology transfer through the Direct Hydrocarbon Indicators mini-symposium at UH and through publications. As a result we have: (1) Tested a new method to directly invert reservoir properties, water saturation, Sw, and porosity from seismic AVO attributes; (2) Constrained the seismic response based on fluid and rock property correlations; (3) Reprocessed seismic data from Ursa field; (4) Compared thin layer property distributions and averaging on AVO response; (5) Related pressures and sorting effects on porosity and their influence on DHI's; (6) Examined and compared gas saturation effects for deep and shallow reservoirs; (7) Performed forward modeling using geobodies from deepwater outcrops; (8) Documented velocities for deepwater sediments; (9) Continued incorporating outcrop descriptive models in seismic forward models; (10) Held an open DHI symposium to present the final results of the project; (11) Relations between Sw, porosity, and AVO attributes; (12) Models of Complex, Layered Reservoirs; and (14) Technology transfer Several factors can contribute to limit our ability to extract accurate hydrocarbon saturations in deep water environments. Rock and fluid properties are one factor, since, for example, hydrocarbon properties will be considerably different with great depths (high pressure) when compared to shallow properties. Significant over pressure, on the other hand will make the rocks behave as if they were shallower. In addition to the physical properties, the scale and tuning will alter our hydrocarbon indicators. Gas saturated reservoirs change reflection amplitudes significantly. The goal for the final project period was to systematically combine and document these various effects for use in deep water exploration and transfer this knowledge as clearly and effectively as possible.

  18. Multiscale Modeling and Simulations of Flows in Naturally Fractured Karst Reservoirs

    E-Print Network [OSTI]

    Popov, Peter

    ) and a free flow region, where the fluid (oil, water, gas) meets no resistance form the surrounding rock [13Multiscale Modeling and Simulations of Flows in Naturally Fractured Karst Reservoirs Peter Popov1-Brinkman equations can naturally be used to model additional physical effects pertaining to vugular media

  19. Lexicographic Optimization of Multiple Economic Objectives in Oil Production from Petroleum Reservoirs

    E-Print Network [OSTI]

    Van den Hof, Paul

    that there is a significant potential to increase life-cycle performance, de- termined using an economic objective function economic life-cycle performance as primary objective and daily production as secondary objective. In the secondary production stage liquid (or gas) is injected into the reservoir using injection wells. The most

  20. TIME-LAPSE VP/VS ANALYSIS FOR RESERVOIR CHARACTERIZATION, RULISON FIELD, COLORADO

    E-Print Network [OSTI]

    from post-stack inversion of P- and S- wave datasets from three (3) time-lapse dedicated 9C surveys-component seismic is used to help with reservoir characterization of tight gas sands via time-lapse VP/VS volumes11 and slow-shear S22) I performed post-stack inversion of the corresponding datasets to obtain

  1. Model Calibration, Drainage Volume Calculation and Optimization in Heterogeneous Fractured Reservoirs 

    E-Print Network [OSTI]

    Kang, Suk Sang 1975-

    2012-08-16

    Density on the Drainage Volumes ....................................................................................... 18 Figure 2.7. (a) Depletion Capacity Map based on Undrained Volumes (b) EUR Map from Exhaustive Simulations... wells, potential infill locations and the estimated ultimate recovery (EUR) computations for infill wells. We propose a rigorous approach for well drainage volume calculations in gas reservoirs based on the flux field derived from dual porosity finite...

  2. URTeC 1620617 Thermal Shock in Reservoir Rock Enhances the Hydraulic

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    URTeC 1620617 Thermal Shock in Reservoir Rock Enhances the Hydraulic Fracturing of Gas Shales Saeid at Austin Copyright 2013, Unconventional Resources Technology Conference (URTeC) This paper was prepared for presentation at the Unconventional Resources Technology Conference held in Denver, Colorado, USA, 12-14 August

  3. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2002-09-30

    The main objectives of the proposed study are as follows: (1) To understand and evaluate an unusual primary oil production mechanism which results in decreasing (retrograde) oil cut (ROC) behavior as reservoir pressure declines. (2) To improve calculations of initial oil in place so as to determine the economic feasibility of completing and producing a well. (3) To optimize the location of new wells based on understanding of geological and petrophysical properties heterogeneities. (4) To evaluate various secondary recovery techniques for oil reservoirs producing from fractured formations. (5) To enhance the productivity of producing wells by using new completion techniques. These objectives are important for optimizing field performance from West Carney Field located in Lincoln County, Oklahoma. The field, which was discovered in 1980, produces from Hunton Formation in a shallow-shelf carbonate reservoir. The early development in the field was sporadic. Many of the initial wells were abandoned due to high water production and constraints in surface facilities for disposing excess produced water. The field development began in earnest in 1995 by Altex Resources. They had recognized that production from this field was only possible if large volumes of water can be disposed. Being able to dispose large amounts of water, Altex aggressively drilled several producers. With few exceptions, all these wells exhibited similar characteristics. The initial production indicated trace amount of oil and gas with mostly water as dominant phase. As the reservoir was depleted, the oil cut eventually improved, making the overall production feasible. The decreasing oil cut (ROC) behavior has not been well understood. However, the field has been subjected to intense drilling activity because of prior success of Altex Resources. In this work, we will investigate the primary production mechanism by conducting several core flood experiments. After collecting cores from representative wells, we will study the wettability of the rock and simulate the depletion behavior by mimicking such behavior under controlled lab conditions.

  4. Using Decline Map Anlaysis (DMA) to Test Well Completion Influence on Gas Production Decline Curves in Barnett Shale (Denton, Wise, and Tarrant Counties) 

    E-Print Network [OSTI]

    Alkassim, Ibrahim

    2010-01-14

    The increasing interest and focus on unconventional reservoirs is a result of the industry's direction toward exploring alternative energy sources. It is due to the fact that conventional reservoirs are being depleted at a fast pace. Shale gas...

  5. Gas hydrates

    SciTech Connect (OSTI)

    Not Available

    1985-04-01

    There is a definite need for the US government to provide leadership for research in gas hydrates and to coordinate its activities with academia, industry, private groups, federal agencies, and their foreign counterparts. In response to this need, the DOE Morgantown Energy Technology Center implemented a gas hydrates R and D program. Understanding the resource will be achieved through: assessment of current technology; characterization of gas hydrate geology and reservoir engineering; and development of diagnostic tools and methods. Research to date has focused on geology. As work progressed, areas where gas hydrates are likely to occur were identified, and specific high potential areas were targeted for future detailed investigation. Initial research activities involved the development of the Geologic Analysis System (GAS); which will provide, through approximately 30 software packages, the capability to manipulate and correlate several types of geologic and petroleum data into maps, graphics, and reports. Preliminary mapping of hydrate prospects for the Alaskan North Slope is underway. Geological research includes physical system characterization which focuses on creating synthetic methane hydrates and developing synthetic hydrate cores using tetrahydrofuran, consolidated rock cores, frost base mixtures, water/ice base mixtures, and water base mixtures. Laboratory work produced measurements of the sonic velocity and electrical resistivity of these synthetic hydrates. During 1983, a sample from a natural hydrate core recovered from the Pacific coast of Guatemala was tested for these properties by METC. More recently, a natural hydrate sample from the Gulf of Mexico was also acquired and testing of this sample is currently underway. In addition to the development of GAS, modeling and systems analysis work focused on the development of conceptual gas hydrate production models. 16 figs., 6 tabs.

  6. Analysis of the dynamics of saturation and pressure close to the wellbore for condensate reservoirs as a tool to optimize liquid production 

    E-Print Network [OSTI]

    Guerra Camargo, Andrea M

    2001-01-01

    Gas condensate reservoirs often exhibit a rapid decline in production with depletion. During early production, liquid dropout accumulates in the near wellbore area and this liquid dropout reduces the effective permeability ...

  7. Reservoir analysis study, Naval Petroleum Reserve No. 1, Elk Hills Field, Kern County, California: Phase 2 report, Executive summary

    SciTech Connect (OSTI)

    Not Available

    1988-07-01

    The Naval Petroleum Reserve No. 1 (Elk Hills) is located in Kern County, California, and is jointly owned by the US Department of Energy and Chevron USA Inc. The Elk Hills Field is presently producing oil and gas from five geologic zones. These zones contain a number of separate and geologically complex reservoirs. Considerable field development and production of oil and gas have occurred since initial estimates of reserves were made. Total cumulative field production through December 1987 is 850 MMBbls of oil, 1.2 Tcf of gas and 648.2 MMBbls of water. In December 1987, field producing rates expressed on a calendar day basis amounted to 110,364 BOPD, 350,946 Mcfd and 230,179 BWPD from 1157 producers. In addition, a total of two reservoirs have gas injection in progress and four reservoirs have water injection in progress and four reservoirs have water injection in progress. Cumulative gas and water injection amounted to 586 Bcf of gas and 330 MMB of water. December 1987 gas and water injection rates amounted to 174 MMcfd and 234 MBWPD, into 129 injectors. In addition, a steamflood pilot program is currently active in the Eastern Shallow Oil Zone. Jerry R. Bergeson and Associates, Inc. (Bergeson) has completed Phase II of the Reservoir Analysis, Naval Petroleum Reserve Number 1, Elk Hills Oilfield, California. The objectives for this phase of the study included the establishment of revised estimates of the original oil and gas-in-place for each of the zones/reservoirs, estimation of the remaining proved developed, proved undeveloped, probable and possible reserves, and assessment of the effects of historical development and production operations and practices on recoverable reserves. 28 figs., 37 tabs.

  8. Sixteenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Cook, J.W.

    1991-01-25

    The Sixteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 23-25, 1991. The Workshop Banquet Speaker was Dr. Mohinder Gulati of UNOCAL Geothermal. Dr. Gulati gave an inspiring talk on the impact of numerical simulation on development of geothermal energy both in The Geysers and the Philippines. Dr. Gulati was the first recipient of The Stanford Geothermal Program Reservoir Engineering Award for Excellence in Development of Geothermal Energy. Dr. Frank Miller presented the award. The registered attendance figure of one hundred fifteen participants was up slightly from last year. There were seven foreign countries represented: Iceland, Italy, Philippines, Kenya, the United Kingdom, Mexico, and Japan. As last year, papers on about a dozen geothermal fields outside the United States were presented. There were thirty-six papers presented at the Workshop, and two papers were submitted for publication only. Attendees were welcomed by Dr. Khalid Aziz, Chairman of the Petroleum Engineering Department at Stanford. Opening remarks were presented by Dr. Roland Horne, followed by a discussion of the California Energy Commission's Geothermal Activities by Barbara Crowley, Vice Chairman; and J.E. ''Ted'' Mock's presentation of the DOE Geothermal Program: New Emphasis on Industrial Participation. Technical papers were organized in twelve sessions concerning: hot dry rock, geochemistry, tracer injection, field performance, modeling, and chemistry/gas. As in previous workshops, session chairpersons made major contributions to the program. Special thanks are due to Joel Renner, Jeff Tester, Jim Combs, Kathy Enedy, Elwood Baldwin, Sabodh Garg, Marcel0 Lippman, John Counsil, and Eduardo Iglesias. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Angharad Jones, Rosalee Benelli, Jeanne Mankinen, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate the audiovisual equipment and to Michael Riley who coordinated the meeting arrangements for a second year. Henry J. Ramey, Jr. Roland N. Horne Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook

  9. An Updated Conceptual Model Of The Los Humeros Geothermal Reservoir...

    Open Energy Info (EERE)

    Humeros Geothermal Reservoir (Mexico) Abstract An analysis of production and reservoir engineering data of 42 wells from the Los Humeros geothermal field (Mexico) allowed...

  10. Assessment of Latent Heat Reservoirs for Thermal Management of...

    Office of Scientific and Technical Information (OSTI)

    Assessment of Latent Heat Reservoirs for Thermal Management of QCW Laser Diodes Citation Details In-Document Search Title: Assessment of Latent Heat Reservoirs for Thermal...

  11. The Effect of Acid Additives on Carbonate Rock Wettability and Spent Acid Recovery in Low Permeability Gas Carbonates 

    E-Print Network [OSTI]

    Saneifar, Mehrnoosh

    2012-10-19

    Spent acid retention in the near-wellbore region causes reduction of relative permeability to gas and eventually curtailed gas production. In low-permeability gas carbonate reservoirs, capillary forces are the key parameters that affect the trapping...

  12. Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico, Class III

    SciTech Connect (OSTI)

    Murphy, Mark B.

    2002-01-16

    The overall objective of this project was to demonstrate that a development program-based on advanced reservoir management methods-can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan included developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals were (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

  13. Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico

    SciTech Connect (OSTI)

    Murphy, Mark B.

    1999-11-01

    The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

  14. Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico, Class III

    SciTech Connect (OSTI)

    Murphy, Michael B.

    2002-02-21

    The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

  15. Top-Down Intelligent Reservoir Modeling of New Albany Shale A. Kalantari-Dahaghi, SPE, S.D. Mohaghegh, SPE, West Virginia University

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    on individual wells in a multi-well New Albany Shale gas reservoir in Western Kentucky that has a reasonable Albany Shale Gas -The New Albany Shale is predominantly an organic-rich brownish-black and grayish-black shale that is present in the subsurface throughout the Illinois Basin. The total gas content of the New

  16. Int. J. Oil, Gas and Coal Technology, Vol. 7, No. 2, 2014 115 Copyright 2014 Inderscience Enterprises Ltd.

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    Int. J. Oil, Gas and Coal Technology, Vol. 7, No. 2, 2014 115 Copyright © 2014 Inderscience fields in Saudi Arabia', Int. J. Oil, Gas and Coal Technology, Vol. 7, No. 2, pp.115­131. Biographical economic recovery of oil and gas from a reservoir. The purpose of reservoir management is to control

  17. Int. J. Oil, Gas and Coal Technology, Vol. 5, No. 1, 2012 1 Copyright 2012 Inderscience Enterprises Ltd.

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    Int. J. Oil, Gas and Coal Technology, Vol. 5, No. 1, 2012 1 Copyright © 2012 Inderscience Enterprises Ltd. Top-Down, Intelligent Reservoir Modeling of Oil and Gas Producing Shale Reservoirs; Case.Bromhal@netl.doe.gov Abstract: Producing hydrocarbon (both oil and gas) from Shale plays has attracted much attention in recent

  18. Performance testing the Phase 2 HDR reservoir

    SciTech Connect (OSTI)

    Ponden, R.F.; Dreesen, D.S. ); Thomson, J.C. )

    1991-01-01

    The geothermal energy program at the Los Alamos National Laboratory is directed toward developing the Hot Dry Rock (HDR) technology as an alternate energy source. Positive results have been obtained in previous circulation tests of HDR reservoirs at the Laboratory's test site in Fenton Hill, New Mexico. There still remains however, the need to demonstrate that adequate geothermal energy can be extracted in an efficient manner to support commercial power production. This year, the Laboratory will begin a circulation test of its Phase 2, reservoir. The objectives of this test are to characterize steady-state power production and long-term reservoir performance. 6 refs., 2 figs., 3 tabs.

  19. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2005-07-01

    West Carney field--one of the newest fields discovered in Oklahoma--exhibits many unique production characteristics. These characteristics include: (1) decreasing water-oil ratio; (2) decreasing gas-oil ratio followed by an increase; (3) poor prediction capability of the reserves based on the log data; and (4) low geological connectivity but high hydrodynamic connectivity. The purpose of this investigation is to understand the principal mechanisms affecting the production, and propose methods by which we can extend the phenomenon to other fields with similar characteristics. In our experimental investigation section, we continue to describe the use of surfactant to alter the wettability of the rock. By altering the wettability, we should be able to change the water-gas ratio in the reservoir and, hence, improve the productivity from the well. In our Engineering and Geological Analysis section, we present our rock typing analysis work which combines the geological data with engineering data to develop a unique rock characteristics description. The work demonstrates that it is possible to incorporate geological description in engineering analysis so that we can come up with rock types which have unique geological characteristics, as well as unique petrophysical characteristics. Using this rock typing scheme, we intend to develop a detailed reservoir description in our next quarterly report.

  20. Natural Gas Monthly, October 1993

    SciTech Connect (OSTI)

    Not Available

    1993-11-10

    The (NGM) Natural Gas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the natural gas industry. Volume and price data are presented each month for natural gas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting natural gas information. This month`s feature articles are: US Production of Natural Gas from Tight Reservoirs: and Expanding Rule of Underground Storage.

  1. Shale Gas Production Theory and Case Analysis We researched the process of oil recovery and shale gas

    E-Print Network [OSTI]

    Huang, Xun

    Shale Gas Production Theory and Case Analysis (Siemens) We researched the process of oil recovery and shale gas recovery and compare the difference between conventional and unconventional gas reservoir and recovery technologies. Then we did theoretical analysis on the shale gas production. According

  2. Bayesian Methods in Reservoir Operations: The Zambezi River Case

    E-Print Network [OSTI]

    West, Mike

    reservoirs in the Zambezi river: Lake Kariba and Cahora Bassa. KEYWORDS: Reservoir operations, Dynamic models, Multiattribute utility, Dynamic programming, Sensitivity analysis. 1 #12; 1 Reservoir operations Many reservoirs, uncertainty has been included, both explicitly (via probabilistic models and techniques) and implic­ itly (via

  3. Reservoir performance characterized in mature steam pattern

    SciTech Connect (OSTI)

    Miller, D.D.; McPherson, J.G.; Covington, T.E.

    1989-04-01

    A detailed reservoir description provided new insight in an investigation of a ten-year-old steam flood. Mobil Oil Corporation conducted this study of the Pleistocene upper Tulare sands in South Belridge field, located in the San Joaquin basin, Kern County, California. The study area is on the gently dipping (6/degrees/) southwestern flank of the South Belridge anticline. Wireline logs from 19 wells in a 10-ac (660 ft x 660 ft) pattern were correlated in detail. Seven post-steam conventional cores (1523 ft) aided (1) the evaluation of vertical and lateral steam-sweep efficiency, (2) evaluation of reservoir and fluid changes due to steam, (3) influence of lithofacies in reservoir quality, and (4) provided insight to the three-dimensional reservoir flow-unit geometries.

  4. Fifteenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Not Available

    1990-01-01

    The Fifteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 23--25, 1990. Major topics included: DOE's geothermal research and development program, well testing, field studies, geosciences, geysers, reinjection, tracers, geochemistry, and modeling.

  5. Reservoir characterization using nonparametric regression techniques 

    E-Print Network [OSTI]

    Mathisen, Trond

    2000-01-01

    reservoirs, but a simple and computationally efficient correlation is developed using only commonly available well log responses. Accurate permeability correlations are essential to understand, forecast, manage, and control production operations...

  6. Estimating uncertainties in integrated reservoir studies 

    E-Print Network [OSTI]

    Zhang, Guohong

    2004-09-30

    existing methods. The integrated mismatch method tends to generate smaller ranges of uncertainty than many existing methods. When starting from nonoptimal reservoir models, in some cases the integrated mismatch method is able to bracket the true reserves...

  7. Study of induced seismicity for reservoir characterization

    E-Print Network [OSTI]

    Li, Junlun, Ph. D. Massachusetts Institute of Technology

    2013-01-01

    The main goal of the thesis is to characterize the attributes of conventional and unconventional reservoirs through passive seismicity. The dissertation is comprised of the development and applications of three new methods, ...

  8. Reservoir fracture characterizations from seismic scattered waves

    E-Print Network [OSTI]

    Fang, Xinding

    2012-01-01

    The measurements of fracture parameters, such as fracture orientation, fracture density and fracture compliance, in a reservoir is very important for field development and exploration. Traditional seismic methods for ...

  9. ANNOTATED RESEARCH BIBLIOGRAPHY FOR GEOTHERMAL RESERVOIR ENGINEERING

    E-Print Network [OSTI]

    Sudo!, G.A

    2012-01-01

    and subsequent change t o a superheated steam state. Faust,for electric power of the superheated steam reservoir a ttwo-phase condition t o superheated steam. Knapp, R. M. and

  10. Pressure maintenance in a volatile oil reservoir 

    E-Print Network [OSTI]

    Schuster, Bruce Alan

    1989-01-01

    PRESSURE MAINTENANCE IN A VOLATILE OIL RESERVOIR A Thesis BRUCE ALAN SCHUSTER Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER OF SCIENCE May, 1989 Major... Subject: Petroleum Engineering PRESSURE MAINTENANCE IN A VOLATILE OIL RESERVOIR A Thesis BRUCE ALAN SCHUSTER Approved as to style and content by: S. A. Holditch (Chair of Committee) W. J. Lee (Member) R. R, Berg (Member) , Jz W. D. Von Gonten...

  11. SEISMIC ATTENUATION FOR RESERVOIR CHARACTERIZATION

    SciTech Connect (OSTI)

    Joel Walls; M.T. Taner; Gary Mavko; Jack Dvorkin

    2002-07-01

    In fully-saturated rock and at ultrasonic frequencies, the microscopic squirt flow induced between the stiff and soft parts of the pore space by an elastic wave is responsible for velocity-frequency dispersion and attenuation. In the seismic frequency range, it is the macroscopic cross-flow between the stiffer and softer parts of the rock. We use the latter hypothesis to introduce simple approximate equations for velocity-frequency dispersion and attenuation in a fully water saturated reservoir. The equations are based on the assumption that in heterogeneous rock and at a very low frequency, the effective elastic modulus of the fully-saturated rock can be estimated by applying a fluid substitution procedure to the averaged (upscaled) dry frame whose effective porosity is the mean porosity and the effective elastic modulus is the Backus-average (geometric mean) of the individual dry-frame elastic moduli of parts of the rock. At a higher frequency, the effective elastic modulus of the saturated rock is the Backus-average of the individual fully-saturated-rock elastic moduli of parts of the rock. The difference between the effective elastic modulus calculated separately by these two methods determines the velocity-frequency dispersion. The corresponding attenuation is calculated from this dispersion by using (e.g.) the standard linear solid attenuation model.

  12. Oil recovery from naturally fractured reservoirs by steam injection methods. Final report

    SciTech Connect (OSTI)

    Reis, J.C.; Miller, M.A.

    1995-05-01

    Oil recovery by steam injection is a proven, successful technology for nonfractured reservoirs, but has received only limited study for fractured reservoirs. Preliminary studies suggest recovery efficiencies in fractured reservoirs may be increased by as much as 50% with the application of steam relative to that of low temperature processes. The key mechanisms enhancing oil production at high temperature are the differential thermal expansion between oil and the pore volume, and the generation of gases within matrix blocks. Other mechanisms may also contribute to increased production. These mechanisms are relatively independent of oil gravity, making steam injection into naturally fractured reservoirs equally attractive to light and heavy oil deposits. The objectives of this research program are to quantify the amount of oil expelled by these recovery mechanisms and to develop a numerical model for predicting oil recovery in naturally fractured reservoirs during steam injection. The experimental study consists of constructing and operating several apparatuses to isolate each of these mechanisms. The first measures thermal expansion and capillary imbibition rates at relatively low temperature, but for various lithologies and matrix block shapes. The second apparatus measures the same parameters, but at high temperatures and for only one shape. A third experimental apparatus measures the maximum gas saturations that could build up within a matrix block. A fourth apparatus measures thermal conductivity and diffusivity of porous media. The numerical study consists of developing transfer functions for oil expulsion from matrix blocks to fractures at high temperatures and incorporating them, along with the energy equation, into a dual porosity thermal reservoir simulator. This simulator can be utilized to make predictions for steam injection processes in naturally-fractured reservoirs. Analytical models for capillary imbibition have also been developed.

  13. Graduation/ Student assistent (9 months) combination: Gas production decline due to salt deposition (NaCl)

    E-Print Network [OSTI]

    Vuik, Kees

    (NaCl) Mentors: Hans Bruining1 (reactive flow, chemistry), Han Velthuis/Aris Twerda (TNO Oil & Gas: · The source of salt in the gas reservoir · The location, rate and field condition dependence of salt precipitation. · How to rinse the near-well bore reservoir efficiently (frequency and amount fresh water washes

  14. An Integrated Study Method For Exploration Of Gas Hydrate Reservoirs...

    Open Energy Info (EERE)

    and geochemistry. First, geological analysis is made using data of material sources, structures, sediments, and geothermal regimes to determine the hydrocarbon-formation conditions...

  15. Criteria for displacement by gas versus water in oil reservoirs 

    E-Print Network [OSTI]

    Piper, Larry Dean

    1981-01-01

    the problem. Croes and SchwarzIp stud1ed the eff1c1ency of water flooding and presented results show1ng effic1ency and water cut as a function of total production for a range of v1scosity rat1os between I and 500. They also used the1r results to compare... of the oil in place at various values of the displac1ng fluid-to-oil ratio (DFOR)* was used as the measure of displacement effic1ency. This procedure was used for two reasons. F1rst, economic limits may be established based on DFOR. Recovery at various...

  16. Predicting horizontal well performance in solution-gas drive reservoirs 

    E-Print Network [OSTI]

    Plahn, Sheldon Von

    1986-01-01

    University Chairman of Advisory Committee: Dr. Richard A. Star tzman Drilling horizontal wells to accelerate the recovery of oil is an old idea, but the practice was not widespread. Due to r ecent improvements in drilling technology, interest in drilling... permeability on hoi izontal 33 well pe formance INTRODUCTION Ba~cc~rLiiI The idea of dr illing horizontal wells to accelei ate the recovery of oil dates back to the 1940's. But, due to a lack of reliable directional drilling techniques and a relatively...

  17. Methodologies for Reservoir Characterization Using Fluid Inclusion Gas

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious RankADVANCED MANUFACTURING OFFICESpecial ReportProposal toDepartment of EnergyDepartment ofFYFYgas is

  18. Pennsylvania Dry Natural Gas New Reservoir Discoveries in Old Fields

    U.S. Energy Information Administration (EIA) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home PageMonthly","10/2015"4,"Ames5 Tables July 1996 Energy Information Administration Office of Coal, Nuclear,DecadeYear JanNewMajor Characteristics ofYear Jan17 34 44 67 58

  19. A combination of streamtube and geostatical simulation methodologies for the study of large oil reservoirs

    SciTech Connect (OSTI)

    Chakravarty, A.; Emanuel, A.S.; Bernath, J.A.

    1997-08-01

    The application of streamtube models for reservoir simulation has an extensive history in the oil industry. Although these models are strictly applicable only to fields under voidage balance, they have proved to be useful in a large number of fields provided that there is no solution gas evolution and production. These models combine the benefit of very fast computational time with the practical ability to model a large reservoir over the course of its history. These models do not, however, directly incorporate the detailed geological information that recent experience has taught is important. This paper presents a technique for mapping the saturation information contained in a history matched streamtube model onto a detailed geostatistically derived finite difference grid. With this technique, the saturation information in a streamtube model, data that is actually statistical in nature, can be identified with actual physical locations in a field and a picture of the remaining oil saturation can be determined. Alternatively, the streamtube model can be used to simulate the early development history of a field and the saturation data then used to initialize detailed late time finite difference models. The proposed method is presented through an example application to the Ninian reservoir. This reservoir, located in the North Sea (UK), is a heterogeneous sandstone characterized by a line drive waterflood, with about 160 wells, and a 16 year history. The reservoir was satisfactorily history matched and mapped for remaining oil saturation. A comparison to 3-D seismic survey and recently drilled wells have provided preliminary verification.

  20. Experimental and simulation studies of water-alternating-enriched gas injection for San Francisco Field, Colombia 

    E-Print Network [OSTI]

    Soto Tavera, Claudia Patricia

    2003-01-01

    This thesis presents a complete investigation involving experimental and compositional reservoir simulation studies into enriched gas injection as a method to enhance oil recovery from the San Francisco field in Colombia. In enriched gas floods...

  1. Applying the isochronal, transient p/z method to gas wells exhibiting wellbore storage effects 

    E-Print Network [OSTI]

    Deshpande, Anil

    1993-01-01

    Static reservoir pressures are required for gas material balance plz vs. Gp plots. A new method has been developed that uses wellbore storage distorted early time pressure buildup data to determine original gas in place (OGIP). Analysis...

  2. Study of Reservoir Heterogencities and Structural Features Affecting Production in the Shallow Oil Zone, Eastern Elk Hills Area, California

    SciTech Connect (OSTI)

    Janice Gillespie

    2004-11-01

    Late Neogene (Plio-Pleistocene) shallow marine strata of the western Bakersfield Arch and Elk Hills produce hydrocarbons from several different reservoirs. This project focuses on the shallow marine deposits of the Gusher and Calitroleum reservoirs in the Lower Shallow Oil Zone (LSOZ). In the eastern part of the study area on the Bakersfield Arch at North and South Coles Levee field and in two wells in easternmost Elk Hills, the LSOZ reservoirs produce dry (predominantly methane) gas. In structurally higher locations in western Elk Hills, the LSOZ produces oil and associated gas. Gas analyses show that gas from the eastern LSOZ is bacterial and formed in place in the reservoirs, whereas gas associated with oil in the western part of the study area is thermogenic and migrated into the sands from deeper in the basin. Regional mapping shows that the gas-bearing LSOZ sands in the Coles Levee and easternmost Elk Hills area are sourced from the Sierra Nevada to the east whereas the oil-bearing sands in western Elk Hills appear to be sourced from the west. The eastern Elk Hills area occupied the basin depocenter, farthest from either source area. As a result, it collected mainly low-permeability offshore shale deposits. This sand-poor depocenter provides an effective barrier to the updip migration of gases from east to west. The role of small, listric normal faults as migration barriers is more ambiguous. Because our gas analyses show that the gas in the eastern LSOZ reservoirs is bacterial, it likely formed in-place near the reservoirs and did not have to migrate far. Therefore, the gas could have been generated after faulting and accumulated within the fault blocks as localized pools. However, bacterial gas is present in both the eastern AND western parts of Elk Hills in the Dry Gas Zone (DGZ) near the top of the stratigraphic section even though the measured fault displacement is greatest in this zone. Bacterial gas is not present in the west in the deeper LSOZ which has less measured fault displacement. The main difference between the DGZ and the LSOZ appears to be the presence of a sandpoor area in the LSOZ in eastern Elk Hills. The lack of permeable migration pathways in this area would not allow eastern bacterial gas to migrate farther updip into western Elk Hills. A similar sand-poor area does not appear to exist in the DGZ but future research may be necessary to verify this.

  3. Application of microturbines to control emissions from associated gas

    DOE Patents [OSTI]

    Schmidt, Darren D.

    2013-04-16

    A system for controlling the emission of associated gas produced from a reservoir. In an embodiment, the system comprises a gas compressor including a gas inlet in fluid communication with an associated gas source and a gas outlet. The gas compressor adjusts the pressure of the associated gas to produce a pressure-regulated associated gas. In addition, the system comprises a gas cleaner including a gas inlet in fluid communication with the outlet of the gas compressor, a fuel gas outlet, and a waste product outlet. The gas cleaner separates at least a portion of the sulfur and the water from the associated gas to produce a fuel gas. Further, the system comprises a gas turbine including a fuel gas inlet in fluid communication with the fuel gas outlet of the gas cleaner and an air inlet. Still further, the system comprises a choke in fluid communication with the air inlet.

  4. The Potosi Reservoir Model 2013

    SciTech Connect (OSTI)

    Adushita, Yasmin; Smith, Valerie; Leetaru, Hannes

    2014-09-30

    As a part of a larger project co-funded by the United States Department of Energy (US DOE) to evaluate the potential of formations within the Cambro-Ordovician strata above the Mt. Simon as potential targets for carbon sequestration in the Illinois and Michigan Basins, the Illinois Clean Coal Institute (ICCI) requested Schlumberger to evaluate the potential injectivity and carbon dioxide (CO2) plume size of the Cambrian Potosi Formation. The evaluation of this formation was accomplished using wireline data, core data, pressure data, and seismic data from the US DOE-funded Illinois Basin–Decatur Project (IBDP) being conducted by the Midwest Geological Sequestration Consortium in Macon County, Illinois. In 2010, technical performance evaluations on the Cambrian Potosi Formation were performed through reservoir modeling. The data included formation tops from mud logs, well logs from the VW1 and the CCS1 wells, structural and stratigraphic formation from three dimensional (3D) seismic data, and field data from several waste water injection wells for Potosi Formation. Intention was for two million tons per annum (MTPA) of CO2 to be injected for 20 years. In the preceding, the 2010 Potosi heterogeneous model (referred to as the "Potosi Dynamic Model 2010" in this topical report) was re-run using a new injection scenario; 3.2 MTPA for 30 years. The extent of the Potosi Dynamic Model 2010, however, appeared too small for the new injection target. It was not sufficiently large enough to accommodate the evolution of the plume. The new model, Potosi Dynamic Model 2013a, was built by extending the Potosi Dynamic Model 2010 grid to 30 miles x 30 miles (48.3km x48.3km), while preserving all property modeling workflows and layering. This model was retained as the base case of Potosi Dynamic Model 2013a. The Potosi reservoir model was updated to take into account the new data from the verification well VW2 which was drilled in 2012. The new porosity and permeability modeling was performed to take into account the log data from the new well. Revisions of the 2010 modeling assumptions were also done on relative permeability, capillary pressures, formation water salinity, and the maximum allowable well bottomhole pressure. Dynamic simulations were run using the injection target of 3.2 MTPA for 30 years. This new dynamic model was named Potosi Dynamic Model 2013b. Due to the major uncertainties on the vugs permeability, two models were built; the Pessimistic and Optimistic Cases. The Optimistic Case assumes vugs permeability of 9,000 mD, which is analog to the vugs permeability identified in the pressure fall off test of a waste water injector in the Tuscola site, approx. 40 miles (64.4km) away from the IBDP area. The Pessimistic Case assumes that the vugs permeability is equal to the log data, which does not take into account the permeability from secondary porosity. The probability of such case is deemed low and could be treated as the worst case scenario, since the contribution of secondary porosity to the permeability is neglected and the loss circulation events might correspond to a much higher permeability. It is considered important, however, to identify the range of possible reservoir performance since there are no rigorous data available for the vugs permeability. The Optimistic Case gives an average CO2 injection rate of 0.8 MTPA and cumulative injection of 26 MT in 30 years, which corresponds to 27% of the injection target. The injection rate is approx. 3.2 MTPA in the first year as the well is injecting into the surrounding vugs, and declines rapidly to 0.8 MTPA in year 4 once the surrounding vugs are full and the CO2 start to reach the matrix. This implies that according to this preliminary model, a minimum of four (4) wells could be required to achieve the injection target. This result is lower than the injectivity estimated in the Potosi Dynamic Model 2013a (43 MT in 30 years), since the permeability model applied in the Potosi Dynamic Model 2013b is more conservative. This revision was deemed necessary to treat the uncerta

  5. Stratigraphy and sedimentation of the Unayzah reservoir, central Saudi Arabia

    SciTech Connect (OSTI)

    Senalp, M.; Abdulaziz, A. [Saudi Aramco, Dhahran (Saudi Arabia)

    1995-08-01

    Significant reserves of Arabian super light oil, condensate, and associated gas occur in the various genetically different sandstone bodies of the upper Permian Unayzah and Khuff Formations in Central Saudi Arabia. The Unayzah Formation which rests unconformably on the older formations is composed of red colored, poorly sorted conglomerate, sandstone, siltstone, mudstone, caliche and nodular anhydrite. Facies changes occur due to the presence of various subenvironments and possible faulting and structural growth in the basin during deposition. However, the entire Unayzah Formation shows an overall fining and thinning-upward sequence. It was deposited as coalescing alluvial fans dominated by braided streams which graded into meandering stream and playa lakes under and to semi-arid conditions. Eolian processes were also inferred. A marked unconformity which is indicated by the occurrence of thick caliche and soil horizons separate the Unayzah and the overlying Khuff Formation. The Khuff Formation consists primarily of marine shale, marl, and fine- to very coarse-grained sandstones in the lower parts; shale, limestone, dolomite, and amhydrite in the upper parts. The sandstones were deposited as incised channel fills and their associated low stand deltaic sediments as a result of fluctuating sea level during the deposition of the Khuff Formation. The base of the incised channels represent a sequence boundary. Red colored and rooted paleosols were formed on the underlying marine sediments. During relative sea level rise, good quality reservoir sands were deposited by aggradation within the incised channels. Sand deposition within the channels terminated at the same time, and the area was covered by shallow marine limestones, shales and marls during maximum sea level highstand. Although the Unayzah reservoir occurs in both the Unayzah and the Khuff Formations because of their different geometry, continuity, and reservoir quality, they have been studied separately.

  6. SEISMIC EVALUATION OF HYDROCARBON SATURATION IN DEEP-WATER RESERVOIRS

    SciTech Connect (OSTI)

    Michael Batzle; D-h Han; R. Gibson; Huw James

    2005-01-22

    During this last quarter of the ''Seismic Evaluation of Hydrocarbon Saturation in Deep-Water Reservoirs'' project (Grant/Cooperative Agreement DE-FC26-02NT15342), we have moved forward on several fronts, including data acquisition as well as analysis and application. During this quarter we have: (1) Completed our site selection (finally); (2) Measured fluid effects in Troika deep water sand sample; (3) Applied the result to Ursa ''fizz gas'' zone; (4) Compared thin layer property averaging on AVO response; (5) Developed target oriented NMO stretch correction; (6) Examined thin bed effects on A-B crossplots; and (7) Begun incorporating outcrop descriptive models in seismic forward models. Several factors can contribute to limit our ability to extract accurate hydrocarbon saturations in deep water environments. Rock and fluid properties are one factor, since, for example, hydrocarbon properties will be considerably different with great depths (high pressure) when compared to shallow properties. Significant over pressure, on the other hand will make the rocks behave as if they were shallower. In addition to the physical properties, the scale and tuning will alter our hydrocarbon indicators. Reservoirs composed of thin bed effects will broaden the reflection amplitude distribution with incident angle. Normal move out (NMO) stretch corrections based on frequency shifts can be applied to offset this effect. Tuning will also disturb the location of extracted amplitudes on AVO intercept and gradient (A-B) plots. Many deep water reservoirs fall this tuning thickness range. Our goal for the remaining project period is to systematically combine and document these various effects for use in deep water exploration.

  7. Seismic signatures of multiphase reservoir fluid distributions: Application to reservoir monitoring

    SciTech Connect (OSTI)

    Packwood, J.L.; Mavko, G.M.

    1995-12-31

    We present an investigation of the effect of multi-phase pore fluid distributions on the seismic velocity of saturated rock as a function of temperature and pressure. The purpose is to show how different fluid distributions might result in different seismic signatures. This is the rock physics link between reservoir simulation and seismic monitoring of hydrocarbon; (1) Uniform effective fluid, (2) Fluid in patches, and (3) Laminated fluid. The latter two models have heterogeneous distributions, and demonstrate that they have the same velocity characteristics. We used Beaver sandstone with a porosity of 6.4% and 5 MPa confining pressure as the rock matrix for our calculations. The uniform fluid model shows poor sensitivity to fluid saturation, with a variation in velocity of less than 1% when gas saturation exceeds 2%. The heterogeneous models show a fairly linear dependence of velocity on saturation with a variation of 7%. We also investigate the effect of oil distillation on seismic velocities during steam flooding. Comparisons velocities calculated using the patches model at temperature of 20{degrees}C and 150{degrees}C, the choice of hydrocarbon components is more critical at high values of oil saturation than at low values of oil saturation. In regions of high oil saturation, there is less than 0.5% variation in velocity using these components. The velocity variation using the effective fluid model at the same conditions is less than 0.5% over the entire range of gas saturation greater than 2%, indicating that the choice of hydrocarbons is not as critical as in the patches model.

  8. Application of integrated reservoir management and reservoir characterization to optimize infill drilling, Class II

    SciTech Connect (OSTI)

    Bergeron, Jack; Blasingame, Tom; Doublet, Louis; Kelkar, Mohan; Freeman, George; Callard, Jeff; Moore, David; Davies, David; Vessell, Richard; Pregger, Brian; Dixon, Bill; Bezant, Bryce

    2000-03-16

    The major purpose of this project was to demonstrate the use of cost effective reservoir characterization and management tools that will be helpful to both independent and major operators for the optimal development of heterogeneous, low permeability carbonate reservoirs such as the North Robertson (Clearfork) Unit.

  9. HYDROPOWER RESERVOIR FOR FLOOD CONTROL: A CASE STUDY ON RINGLET RESERVOIR, CAMERON

    E-Print Network [OSTI]

    Julien, Pierre Y.

    HYDROPOWER RESERVOIR FOR FLOOD CONTROL: A CASE STUDY ON RINGLET RESERVOIR, CAMERON HIGHLANDS, Malaysia 4 Professor, Department of Civil Engineering, Colorado State University, USA ABSTRACT: Hydropower as possible for daily hydropower generation as well as to prevent any spillage at dam. However

  10. Application of reservoir characterization and advanced technology to improve recovery and economics in a lower quality shallow shelf carbonate reservoir. [Quarterly report], October 1, 1995--December 31, 1995

    SciTech Connect (OSTI)

    Taylor, A.R.

    1996-01-01

    West Welch Unit is one of four large waterflood units in the Welch Field in the northwestern portion of Dawson County, TX. This field was discovered early 1940`s and produces oil under a solution gas drive mechanism from the Sand Adres formation at {approx}4800 ft. This field has been under waterflood for 30 yr and a significant portion has been infill drilled on 20-ac density. A 1982-86 CO{sub 2} injection project in the offsetting South Welch Unit yielded positive results. Recent installation of a CO{sub 2} pipeline near the field allowed phased development of a miscible CO{sub 2} injection project at the South Welch Unit. Reservoir quality is poorer at West Welch Unit due to relative position to sea level during deposition, and this unit is ideal for demonstrating methods for enhancing economics of IOR projects in lower quality SSC (shallow shelf carbonate) reservoirs. This Class 2 project concentrates on the efficient design of a miscible CO{sub 2} project based on detailed reservoir characterization. During the quarter, progress was made on petrophysical analysis and tomography processing. The geologic model is dependent on these, and the actual reservoir simulation cannot start until the geologic model is complete, although all the preliminary simulation work is being done.

  11. Seismic imaging of reservoir flow properties: Resolving waterinflux and reservoir permeability

    SciTech Connect (OSTI)

    Vasco, D.W.; Keers, Henk

    2006-11-27

    Methods for geophysical model assessment, in particuale thecomputation of model parameter resolution, indicate the value and thelimitations of time-lapse data in estimating reservoir flow properties. Atrajectory-based method for computing sensitivities provides an effectivemeans to compute model parameter resolutions. We examine the commonsituation in which water encroaches into a resrvoir from below, as due tothe upward movement of an oil-water contact. Using straight-forwardtechniques we find that, by inclusing reflections off the top and bottomof a reservoir tens of meters thick, we can infer reservoir permeabilitybased upon time-lapse data. We find that, for the caseof water influxfrom below, using multiple time-lapse 'snapshots' does not necessarilyimprove the resolution of reservoir permeability. An application totime-lapse data from the Norne field illustrates that we can resolve thepermeability near a producing well using reflections from threeinterfaces associated with the reservoir.

  12. Reservoir Characterization, Production Characteristics, and Research Needs for Fluvial/Alluvial Reservoirs in the United States

    SciTech Connect (OSTI)

    Cole, E.L.; Fowler, M.L.; Jackson, S.R.; Madden, M.P.; Raw-Schatzinger, V.; Salamy, S.P.; Sarathi, P.; Young, M.A.

    1999-04-28

    The Department of Energy's (DOE's) Oil Recovery Field Demonstration Program was initiated in 1992 to maximize the economically and environmentally sound recovery of oil from known domestic reservoirs and to preserve access to this resource. Cost-shared field demonstration projects are being initiated in geology defined reservoir classes which have been prioritized by their potential for incremental recovery and their risk of abandonment. This document defines the characteristics of the fifth geological reservoir class in the series, fluvial/alluvial reservoirs. The reservoirs of Class 5 include deposits of alluvial fans, braided streams, and meandering streams. Deposit morphologies vary as a complex function of climate and tectonics and are characterized by a high degree of heterogeneity to fluid flow as a result of extreme variations in water energy as the deposits formed.

  13. Process Design and Integration of Shale Gas to Methanol 

    E-Print Network [OSTI]

    Ehlinger, Victoria M.

    2013-02-04

    Recent breakthroughs in horizontal drilling and hydraulic fracturing technology have made huge reservoirs of previously untapped shale gas and shale oil formations available for use. These new resources have already made a significant impact...

  14. Pressure transient test analysis of vuggy naturally fractured carbonate reservoir: field case study 

    E-Print Network [OSTI]

    Ajayi, Babatunde Tolulope

    2009-06-02

    Well pressure transient analysis is widely used in reservoir management to obtain reservoir information needed for reservoir simulation, damage identification, well optimization and stimulation evaluation. The main objective ...

  15. Pressure and fluid saturation prediction in a multicomponent reservoir, using combined seismic and electromagnetic imaging

    E-Print Network [OSTI]

    Hoversten, G.M.; Gritto, Roland; Washbourne, John; Daley, Tom

    2002-01-01

    change in reservoir pressure, water saturation, and CO 2 /? ? ) in reservoir pressure, fluid saturations, and theand water saturation within a reservoir without significant

  16. Eolian reservoir characteristics predicted from dune type

    SciTech Connect (OSTI)

    Kocurek, G.; Nielson, J.

    1985-02-01

    The nature of eolian-dune reservoirs is strongly influenced by stratification types (in decreasing order of quality: grain-flow, grain-fall, wind-ripple deposits) and their packaging by internal bounding surfaces. These are, in turn, a function of dune surface processes and migration behavior, allowing for predictive models of reservoir behavior. Migrating, simple crescentic dunes produce tabular bodies consisting mainly of grain-flow cross-strata, and form the best, most predictable reservoirs. Reservoir character improves as both original dune height and preserved set thickness increase, because fewer grain-fall deposits and a lower percentage of dune-apron deposits occur in the cross-strata, respectively. It is probable that many linear and star dunes migrate laterally, leaving a blanket of packages of wind ripple laminae reflecting deposition of broad, shifting aprons. This is distinct from models generated by freezing large portions of these dunes in place. Trailing margins of linear and star dunes are prone to reworking by sand-sheet processes that decrease potential reservoir quality. The occurrence of parabolic dunes isolated on vegetated sand sheets results in a core of grain-flow and grain-fall deposits surrounded by less permeable and porous deposits. Compound crescentic dunes, perhaps the most preservable dune type, may yield laterally (1) single sets of cross-strate, (2) compound sets derived from superimposed simple dunes, or (3) a complex of diverse sets derived from superimposed transverse and linear elements.

  17. SEISMIC AND ROCK PHYSICS DIAGNOSTICS OF MULTISCALE RESERVOIR TEXTURES

    SciTech Connect (OSTI)

    Gary Mavko

    2004-08-01

    As part of our study on ''Relationships between seismic properties and rock microstructure'', we have continued our work on analyzing well logs and microstructural constraints on seismic signatures. We report results of three studies in this report. The first one deals with fractures and faults that provide the primary control on the underground fluid flow through low permeability massive carbonate rocks. Fault cores often represent lower transmissibility whereas the surrounding damaged rocks and main slip surfaces are high transmissibility elements. We determined the physical properties of fault rocks collected in and around the fault cores of large normal faults in central Italy. After studying the P- and S-wave velocity variation during cycles of confining pressure, we conclude that a rigid pore frame characterizes the fault gouge whereas the fractured limestone comprises pores with a larger aspect ratio. The second study was to characterize the seismic properties of brine as its temperature decreases from 25 C to -21 C. The purpose was to understand how the transmitted wave changes with the onset of freezing. The main practical reason for this experiment was to use partially frozen brine as an analogue for a mixture of methane hydrate and water present in the pore space of a gas hydrate reservoir. In the third study we analyzed variations in dynamic moduli in various carbonate reservoirs. The investigations include log and laboratory data from velocity, porosity, permeability, and attenuation measurements.

  18. SEISMIC ATTENUATION FOR RESERVOIR CHARACTERIZATION

    SciTech Connect (OSTI)

    Joel Walls; M.T. Taner; Naum Derzhi; Gary Mavko; Jack Dvorkin

    2003-10-01

    In this report we will show the fundamental concepts of two different methods to compute seismic energy absorption. The first methods gives and absolute value of Q and is based on computation with minimum phase operators. The second method gives a relative energy loss compared to a background trend. This method is a rapid, qualitative indicator of anomalous absorption and can be combined with other attributes such as band limited acoustic impedance to indicate areas of likely gas saturation.

  19. Gravimetric monitoring of gas production from the Troll field Ola Eiken*, Statoil, Mark Zumberge, Scripps Institution of Oceanography, Torkjell Stenvold, Norwegian

    E-Print Network [OSTI]

    Nooner, Scott

    , but there are uncertainties related to parameters such as reservoir volume, total porosity and residual gas saturation across of the seafloor. The estimated average depth change above the reservoir is 0.5 to 0.8 cm, which is likely due to water influx into the reservoir. The result is in agreement with model

  20. Influence of Tributaries on Salinity of Amistad International Reservoir 

    E-Print Network [OSTI]

    Miyamoto, S.; Yuan, Fasong; Anand, Shilpa

    2006-01-01

    in the reservoir was computed as the difference between salt loading and unloading. The unloading components considered were outflow from the Reservoir, seepage losses, and salt storage in the stored water as well as in the bank of the Reservoir. Seepage losses... were estimated by multiplying the mean salinity of the Reservoir to the seepage losses estimated as a sum of the spring flow below the Reservoir. The salt storage in the reservoir bank was estimated as the evapotranspiration losses from the bank when...

  1. ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM

    SciTech Connect (OSTI)

    Mark B. Murphy

    2002-09-30

    The overall objective of this project is to demonstrate that a development program-based on advanced reservoir management methods-can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry. This is the twenty-eighth quarterly progress report on the project. Results obtained to date are summarized.

  2. Reservoir analysis study, Naval Petroleum Reserve No. 1, Elk Hills Field, Kern County, California: Phase 2 report, Volume 1

    SciTech Connect (OSTI)

    Not Available

    1988-06-01

    Jerry R. Bergeso and Associates, Inc. (Bergeson) has completed Phase II of the Reservoir Analysis, Naval Petroleum Reserve Number 1, Elk Hills Oilfield, California. The objectives for this phase of the study included the establishment of revised estimates of the original oil and gas-in-place for each of the zones/reservoirs, estimation of the remaining proved developed, proved undeveloped, probable and possible reserves, and assessment of the effects of historical development and production operations and practices on recoverable reserves. Volume one contains the following: summary; introduction; and reservoir studies for tulare, dry gas zone, eastern shallow oil zone, western shallow oil zone, and Stevens --MBB/W31S, 31S NA/D.

  3. U.S. crude oil, natural gas, and natural gas liquids reserves 1997 annual report

    SciTech Connect (OSTI)

    Wood, John H.; Grape, Steven G.; Green, Rhonda S.

    1998-12-01

    This report presents estimates of proved reserves of crude oil, natural gas, and natural gas liquids as of December 31, 1997, as well as production volumes for the US and selected States and State subdivisions for the year 1997. Estimates are presented for the following four categories of natural gas: total gas (wet after lease separation), nonassociated gas and associated-dissolved gas (which are the two major types of wet natural gas), and total dry gas (wet gas adjusted for the removal of liquids at natural gas processing plants). In addition, reserve estimates for two types of natural gas liquids, lease condensate and natural gas plant liquids, are presented. Also included is information on indicated additional crude oil reserves and crude oil, natural gas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1997 is provided. 21 figs., 16 tabs.

  4. Horizontal well applications in complex carbonate reservoirs

    SciTech Connect (OSTI)

    Rahman, M.; Al-Awami, H.

    1995-10-01

    Over the past four years, Saudi Aramco has drilled over eighty horizontal wells, onshore and offshore. It has successfully applied this technology to develop new reservoirs as well as enhance recovery from its mature fields. This paper presents the reservoir engineering aspects of `horizontal` and `high angle` wells drilled in a major offshore field in Saudi Arabia. It shows how horizontal wells have (a) increased the recovery of bypassed oil, (b) improved well productivity in tight reservoirs, (c) increased production from thin oil zones underlain by water, and (d) improved peripheral injection. The paper discusses the actual performance of the horizontal wells and compares them with offset conventional wells. It presents the results of logging and testing of these wells, and highlights actual field data on (a) relationship between productivity gain and horizontal length, (b) pressure loss along the horizontal wellbore, and (c) effect of heterogeneity on coning an inflow performance.

  5. Application of reservoir characterization and advanced technologies to improve recovery and economics in a lower quality shallow shelf Sand Andreas Reservoir: Quarterly technical report, January 1, 1997--March 31, 1997

    SciTech Connect (OSTI)

    Taylor, A.R., Hickman, T.S., Justice, J.J.

    1997-04-30

    The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: l.Advanced petrophysics 1547 2.Three-dimensional (3-D) seismic 3.Cross-well bore tomography 4.Advanced reservoir simulation 5.Carbon dioxide (CO{sub 2}) stimulation treatments 6.Hydraulic fracturing design and monitoring 7. Mobility control agents SUMMARY OF TECHNICAL PROGRESS West Welch Unit is one of four large waterflood units in the Welch Field in the northwestern portion of Dawson County, Texas. The Welch Field was discovered in the early 1940`s and produces oil under a solution gas drive mechanism from the San Andres formation at approximately 4800 ft. The field has been under waterflood for 30 years and a significant portion has been infill-drilled on 20-ac density. A 1982- 86 Pilot C0{sub 2} injection project in the offsetting South Welch Unit yielded positive results. Recent installation of a C0{sub 2} pipeline near the field allowed the phased development of a miscible CO injection project at the South Welch Unit.

  6. An Intelligent Systems Approach to Reservoir Characterization

    SciTech Connect (OSTI)

    Shahab D. Mohaghegh; Jaime Toro; Thomas H. Wilson; Emre Artun; Alejandro Sanchez; Sandeep Pyakurel

    2005-08-01

    Today, the major challenge in reservoir characterization is integrating data coming from different sources in varying scales, in order to obtain an accurate and high-resolution reservoir model. The role of seismic data in this integration is often limited to providing a structural model for the reservoir. Its relatively low resolution usually limits its further use. However, its areal coverage and availability suggest that it has the potential of providing valuable data for more detailed reservoir characterization studies through the process of seismic inversion. In this paper, a novel intelligent seismic inversion methodology is presented to achieve a desirable correlation between relatively low-frequency seismic signals, and the much higher frequency wireline-log data. Vertical seismic profile (VSP) is used as an intermediate step between the well logs and the surface seismic. A synthetic seismic model is developed by using real data and seismic interpretation. In the example presented here, the model represents the Atoka and Morrow formations, and the overlying Pennsylvanian sequence of the Buffalo Valley Field in New Mexico. Generalized regression neural network (GRNN) is used to build two independent correlation models between; (1) Surface seismic and VSP, (2) VSP and well logs. After generating virtual VSP's from the surface seismic, well logs are predicted by using the correlation between VSP and well logs. The values of the density log, which is a surrogate for reservoir porosity, are predicted for each seismic trace through the seismic line with a classification approach having a correlation coefficient of 0.81. The same methodology is then applied to real data taken from the Buffalo Valley Field, to predict inter-well gamma ray and neutron porosity logs through the seismic line of interest. The same procedure can be applied to a complete 3D seismic block to obtain 3D distributions of reservoir properties with less uncertainty than the geostatistical estimation methods. The intelligent seismic inversion method should help to increase the success of drilling new wells during field development.

  7. Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM. Quarterly technical progress report

    SciTech Connect (OSTI)

    Murphy, M.B.

    1996-04-22

    The overall objective of this project is to demonstrate that development program based on advanced reservoir management methods can significantly improve oil recovery. The demonstration plan includes developing a control area using standard reservoir management techniques and comparing the performance of the control area with an area developed using advanced reservoir management methods. specific goals to attain the objective are (1) to demonstrate that development drilling program and pressure maintenance program, based on advanced reservoir management methods , can significantly improve oil recovery compared with existing technology applications, and (2) to transfer the advanced methodologies to oil and gas producers in the Permian Basin and elsewhere in the US oil and gas industry. This is the second quarterly progress report on the project. Results obtained to date are summarized.

  8. Challenges, uncertainties and issues facing gas production from gas hydrate deposits

    SciTech Connect (OSTI)

    Moridis, G.J.; Collett, T.S.; Pooladi-Darvish, M.; Hancock, S.; Santamarina, C.; Boswell, R.; Kneafsey, T.; Rutqvist, J.; Kowalsky, M.; Reagan, M.T.; Sloan, E.D.; Sum, A.K.; Koh, C.

    2010-11-01

    The current paper complements the Moridis et al. (2009) review of the status of the effort toward commercial gas production from hydrates. We aim to describe the concept of the gas hydrate petroleum system, to discuss advances, requirement and suggested practices in gas hydrate (GH) prospecting and GH deposit characterization, and to review the associated technical, economic and environmental challenges and uncertainties, including: the accurate assessment of producible fractions of the GH resource, the development of methodologies for identifying suitable production targets, the sampling of hydrate-bearing sediments and sample analysis, the analysis and interpretation of geophysical surveys of GH reservoirs, well testing methods and interpretation of the results, geomechanical and reservoir/well stability concerns, well design, operation and installation, field operations and extending production beyond sand-dominated GH reservoirs, monitoring production and geomechanical stability, laboratory investigations, fundamental knowledge of hydrate behavior, the economics of commercial gas production from hydrates, and the associated environmental concerns.

  9. Non-uniqueness problem in estimating original gas in place 

    E-Print Network [OSTI]

    El-Ahmady, Mohamed Hamed

    2000-01-01

    This thesis demonstrates the problem of non-uniqueness in estimating Original Gas in Place of gas reservoirs using the material balance technique. The presence of this non-uniqueness problem can cause an overestimation of the Original Gas in Place...

  10. Water's Journey Through the Shale Gas Drilling and

    E-Print Network [OSTI]

    Walter, M.Todd

    Water's Journey Through the Shale Gas Drilling and Production Processes in the Mid-Atlantic Region: Marcellus shale drilling in progress, Beaver Run Reservoir, Westmoreland County. Credit: Robert Donnan. Gas in the Marcellus shale natural gas industry in the Mid-Atlantic region. Using publicly available information, we

  11. Northwestern University Technological Institute Tight Shale Gas-Hydraulic Fracturing

    E-Print Network [OSTI]

    Guo, Dongning

    Northwestern University Technological Institute Tight Shale Gas-Hydraulic Fracturing Seminar Series Where are we Today: Reservoir and Completion Quality Is Tight Shale Gas and Oil the Answer ? Sidney and with different economic and environmental impacts · Tight Shale Gas and Oil is at least part of the answer

  12. Microbial Dynamics and Control in Shale Gas Production Jason Gaspar,

    E-Print Network [OSTI]

    Alvarez, Pedro J.

    Microbial Dynamics and Control in Shale Gas Production Jason Gaspar, Jacques Mathieu, Yu Yang, Ross effects in shale gas production, such as reservoir souring, plugging, equipment corrosion, and a decrease fluids, drilling mud, and impoundment water likely introduce deleterious microorganisms into shale gas

  13. SEISMIC ATTENUATION FOR RESERVOIR CHARACTERIZATION

    SciTech Connect (OSTI)

    Joel Walls; M.T. Taner; Naum Derzhi; Gary Mavko; Jack Dvorkin

    2003-04-01

    In this report we will show results of seismic and well log derived attenuation attributes from a deep water Gulf of Mexico data set. This data was contributed by Burlington Resources and Seitel Inc. The data consists of ten square kilometers of 3D seismic data and three well penetrations. We have computed anomalous seismic absorption attributes on the seismic data and have computed Q from the well log curves. The results show a good correlation between the anomalous absorption (attenuation) attributes and the presence of gas as indicated by well logs.

  14. SEISMIC ATTENUATION FOR RESERVOIR CHARACTERIZATION

    SciTech Connect (OSTI)

    Joel Walls; M.T. Taner; Naum Derzhi; Gary Mavko; Jack Dvorkin

    2003-04-01

    In this report we will show some new Q related seismic attributes on the Burlington-Seitel data set. One example will be called Energy Absorption Attribute (EAA) and is based on a spectral analysis. The EAA algorithm is designed to detect a sudden increase in the rate of exponential decay in the relatively higher frequency portion of the spectrum. In addition we will show results from a hybrid attribute that combines attenuation with relative acoustic impedance to give a better indication of commercial gas saturation.

  15. Improved characterization of reservoir behavior by integration of reservoir performances data and rock type distributions

    SciTech Connect (OSTI)

    Davies, D.K.; Vessell, R.K.; Doublet, L.E.

    1997-08-01

    An integrated geological/petrophysical and reservoir engineering study was performed for a large, mature waterflood project (>250 wells, {approximately}80% water cut) at the North Robertson (Clear Fork) Unit, Gaines County, Texas. The primary goal of the study was to develop an integrated reservoir description for {open_quotes}targeted{close_quotes} (economic) 10-acre (4-hectare) infill drilling and future recovery operations in a low permeability, carbonate (dolomite) reservoir. Integration of the results from geological/petrophysical studies and reservoir performance analyses provide a rapid and effective method for developing a comprehensive reservoir description. This reservoir description can be used for reservoir flow simulation, performance prediction, infill targeting, waterflood management, and for optimizing well developments (patterns, completions, and stimulations). The following analyses were performed as part of this study: (1) Geological/petrophysical analyses: (core and well log data) - {open_quotes}Rock typing{close_quotes} based on qualitative and quantitative visualization of pore-scale features. Reservoir layering based on {open_quotes}rock typing {close_quotes} and hydraulic flow units. Development of a {open_quotes}core-log{close_quotes} model to estimate permeability using porosity and other properties derived from well logs. The core-log model is based on {open_quotes}rock types.{close_quotes} (2) Engineering analyses: (production and injection history, well tests) Material balance decline type curve analyses to estimate total reservoir volume, formation flow characteristics (flow capacity, skin factor, and fracture half-length), and indications of well/boundary interference. Estimated ultimate recovery analyses to yield movable oil (or injectable water) volumes, as well as indications of well and boundary interference.

  16. INCREASING WATERFLOOD RESERVES IN THE WILMINGTON OIL FIELD THROUGH IMPROVED RESERVOIR CHARACTERIZATION AND RESERVOIR MANAGEMENT

    SciTech Connect (OSTI)

    Scott Walker; Chris Phillips; Roy Koerner; Don Clarke; Dan Moos; Kwasi Tagbor

    2002-02-28

    This project increased recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs. Transferring technology so that it can be applied in other sections of the Wilmington Field and by operators in other slope and basin reservoirs is a primary component of the project. This project used advanced reservoir characterization tools, including the pulsed acoustic cased-hole logging tool, geologic three-dimensional (3-D) modeling software, and commercially available reservoir management software to identify sands with remaining high oil saturation following waterflood. Production from the identified high oil saturated sands was stimulated by recompleting existing production and injection wells in these sands using conventional means as well as a short radius redrill candidate. Although these reservoirs have been waterflooded over 40 years, researchers have found areas of remaining oil saturation. Areas such as the top sand in the Upper Terminal Zone Fault Block V, the western fault slivers of Upper Terminal Zone Fault Block V, the bottom sands of the Tar Zone Fault Block V, and the eastern edge of Fault Block IV in both the Upper Terminal and Lower Terminal Zones all show significant remaining oil saturation. Each area of interest was uncovered emphasizing a different type of reservoir characterization technique or practice. This was not the original strategy but was necessitated by the different levels of progress in each of the project activities.

  17. Seawater can damage Saudi sandstone oil reservoirs

    SciTech Connect (OSTI)

    Dahab, A.S. (King Saud Univ., Riyadh (SA))

    1990-12-10

    Experiments have shown that formation damage from waterflooding of the Aramco and Alkhafji sandstones of Saudi Arabia will not occur if the salinity of the injected brines is higher than 20% NaCl. Because the connate water in these reservoirs has a high salt content of up to 231,000 ppm, Saudi oil fields are almost always susceptible to formation damage when flooded with seawater (about 38,500 ppm). The productive behavior of a reservoir can be affected by clay crystals developed within rock pores.

  18. Simulation studies to evaluate the effect of fracture closure on the performance of naturally fractured reservoirs. Annual report

    SciTech Connect (OSTI)

    Not Available

    1991-10-01

    The first of a three-year research program to evaluate the effect of fracture closure on the recovery of oil and gas from naturally fractured reservoirs has been completed. The objectives of the study are to (1) evaluate the reservoir conditions where fracture closure is significant, and (2) evaluate innovative fluid injection techniques capable of maintaining pressure within the reservoir. Simulation studies were conducted with a dual porosity simulator capable of simulating the performance of vertical and horizontal wells. Each simulator was initialized using properties typical of the Austin Chalk reservoir in Pearsall Field, Texas. Simulations of both vertical and horizontal well performance were made assuming that fracture permeability was insensitive to pressure change. Sensitivity runs indicate that the simulator is predicting the effects of critical reservoir parameters in a logical and consistent manner. The results to-date confirm that horizontal wells can increase both oil recovery rate and total oil recovery from naturally fractured reservoirs. The year one simulation results will provide the baseline for the ongoing study which will evaluate the performance degradation caused by the sensitivity of fracture permeability to pressure change, and investigate fluid injection pressure maintenance as a means to improve oil recovery performance. The study is likely to conclude that fracture closure decreases oil recovery and that pressure support achieved through fluid injection could be beneficial in improving recovery.

  19. DEVELOPMENT OF RESERVOIR CHARACTERIZATION TECHNIQUES AND PRODUCTION MODELS FOR EXPLOITING NATURALLY FRACTURED RESERVOIRS

    SciTech Connect (OSTI)

    Michael L. Wiggins; Raymon L. Brown; Faruk Civan; Richard G. Hughes

    2002-12-31

    For many years, geoscientists and engineers have undertaken research to characterize naturally fractured reservoirs. Geoscientists have focused on understanding the process of fracturing and the subsequent measurement and description of fracture characteristics. Engineers have concentrated on the fluid flow behavior in the fracture-porous media system and the development of models to predict the hydrocarbon production from these complex systems. This research attempts to integrate these two complementary views to develop a quantitative reservoir characterization methodology and flow performance model for naturally fractured reservoirs. The research has focused on estimating naturally fractured reservoir properties from seismic data, predicting fracture characteristics from well logs, and developing a naturally fractured reservoir simulator. It is important to develop techniques that can be applied to estimate the important parameters in predicting the performance of naturally fractured reservoirs. This project proposes a method to relate seismic properties to the elastic compliance and permeability of the reservoir based upon a sugar cube model. In addition, methods are presented to use conventional well logs to estimate localized fracture information for reservoir characterization purposes. The ability to estimate fracture information from conventional well logs is very important in older wells where data are often limited. Finally, a desktop naturally fractured reservoir simulator has been developed for the purpose of predicting the performance of these complex reservoirs. The simulator incorporates vertical and horizontal wellbore models, methods to handle matrix to fracture fluid transfer, and fracture permeability tensors. This research project has developed methods to characterize and study the performance of naturally fractured reservoirs that integrate geoscience and engineering data. This is an important step in developing exploitation strategies for optimizing the recovery from naturally fractured reservoir systems. The next logical extension of this work is to apply the proposed methods to an actual field case study to provide information for verification and modification of the techniques and simulator. This report provides the details of the proposed techniques and summarizes the activities undertaken during the course of this project. Technology transfer activities were highlighted by a two-day technical conference held in Oklahoma City in June 2002. This conference attracted over 90 participants and included the presentation of seventeen technical papers from researchers throughout the United States.

  20. Research program on fractured petroleum reservoirs. Final report, January 1, 1996--December 31, 1996

    SciTech Connect (OSTI)

    Firoozabadi, A.

    1997-05-01

    Multiphase flow in fractured porous media is a complex problem. While the study of single phase flow in a fractured or a layered medium can be pursued by some kind of averaging process, there is no meaning to averaging two-phase flow when capillarity is an active force. For a two-layer system comprised of high and low permeable layers, the performance of gas-oil gravity can be less efficient than the homogeneous low permeable medium. On the other hand, heterogeneity may enhance water imbibition due to capillarity. Due to the above and various other complexities, current tools for predicting the performance of fractured hydrocarbon reservoirs are not reliable. Based on the research work carried out at the Reservoir Engineering Research Institute, and some other Institutions, a good deal of progress has been made in recent years. But still we are a long way from good predictive reservoir models. In this final report, we summarize some of our achievements in the understanding of multiphase flow in fractured media. Since some of the features of two-phase flow in fractured and layered many are similar due to the capillary forces, the work includes progress in both types of media. There are some basic issues of flow in both fractured and unfractured media that are currently unresolved. These issues include: (1) new phase formation such as the formation of liquid phase in gas condensate reservoirs, and gas phase formation in solution gas drive process and (2) composition variation due to thermal convection and diffusion processes. In the following, a brief summary of our findings in the last three years during the course of the project is presented.

  1. Characteristics of the C Shale and D Shale reservoirs, Monterey Formation, Elk Hills Field, Kern County, California

    SciTech Connect (OSTI)

    Reid, S.A.; McIntyre, J.L. [Bechtel Petroleum Operations, Inc., Tupman, CA (United States); McJannet, G.S. [Dept. of Energy, Tupman, CA (United States)

    1996-12-31

    The upper Miocene C Shale and D Shale reservoirs of the Elk Hills Shale Member of the Monterey Formation have cumulative oil and gas production much higher than the originally estimated recovery. These San Joaquin basin reservoirs are the lowest of the Stevens producing zones at Elk Hills and currently produce from a 2800-acre area on the 31 S anticline. The C Shale contains lower slope and basin plain deposits of very fine grained, thinly bedded, graded turbidites, pelagic and hemipelagic claystone, and slump deposits. Although all units are oil-bearing, only the lower parts of the graded turbidity intervals have sufficient horizontal permeability to produce oil. The D Shale consists of chart, claystone, carbonates and slump deposits, also originating in a lower slope to basin plain setting. All D Shale rock types contain oil, but the upper chart interval is the most productive. The chart has high matrix porosity, and due to a complex horizontal and vertical microfracture system, produces at a highly effective rate. Core samples indicate more oil-in-place is present in the thin, graded C Shale beds and in the porous D Shale chart than is identifiable from conventional electric logs. High gas recovery rates are attributed mostly to this larger volume of associated oil. Gas also enters the reservoirs from the adjacent 26R reservoir through a leaky normal fault. Significant gas volumes also may desorb from immature organic material common in the rock matrix.

  2. Characteristics of the C Shale and D Shale reservoirs, Monterey Formation, Elk Hills Field, Kern County, California

    SciTech Connect (OSTI)

    Reid, S.A.; McIntyre, J.L. (Bechtel Petroleum Operations, Inc., Tupman, CA (United States)); McJannet, G.S. (Dept. of Energy, Tupman, CA (United States))

    1996-01-01

    The upper Miocene C Shale and D Shale reservoirs of the Elk Hills Shale Member of the Monterey Formation have cumulative oil and gas production much higher than the originally estimated recovery. These San Joaquin basin reservoirs are the lowest of the Stevens producing zones at Elk Hills and currently produce from a 2800-acre area on the 31 S anticline. The C Shale contains lower slope and basin plain deposits of very fine grained, thinly bedded, graded turbidites, pelagic and hemipelagic claystone, and slump deposits. Although all units are oil-bearing, only the lower parts of the graded turbidity intervals have sufficient horizontal permeability to produce oil. The D Shale consists of chart, claystone, carbonates and slump deposits, also originating in a lower slope to basin plain setting. All D Shale rock types contain oil, but the upper chart interval is the most productive. The chart has high matrix porosity, and due to a complex horizontal and vertical microfracture system, produces at a highly effective rate. Core samples indicate more oil-in-place is present in the thin, graded C Shale beds and in the porous D Shale chart than is identifiable from conventional electric logs. High gas recovery rates are attributed mostly to this larger volume of associated oil. Gas also enters the reservoirs from the adjacent 26R reservoir through a leaky normal fault. Significant gas volumes also may desorb from immature organic material common in the rock matrix.

  3. Reservoir analysis study, Naval Petroleum Reserve No. 1, Elk Hills Field, Kern County, California: Phase 2 report: Volume 1, Appendices

    SciTech Connect (OSTI)

    Not Available

    1988-06-01

    The objectives for the Phase II study included the establishment of revised estimates of the original oil and gas-in-place for each of the zones/reservoirs, estimation of the remaining proved developed, proved undeveloped, probable and possible reserves, and assessment of the effects of historical development and production operations and practices on recoverable reserves. 43 figs., 103 tabs.

  4. Monitoring and Modeling Fluid Flow in a Developing EGS Reservoir

    Broader source: Energy.gov [DOE]

    Project objectives: Better understand and model fluid injection into a tight reservoir on the edges of a hydrothermal field. Use seismic data to constrain geomechanical/hydrologic/thermal model of reservoir.

  5. Reservoir Simulation Used to Plan Diatomite Developement in Mountainous Region 

    E-Print Network [OSTI]

    Powell, Richard

    2012-10-19

    -10 md) and high viscosity (~220 cp) at the reservoir temperature. Cyclic steam injection has been widely used in diatomite reservoirs to take advantage of the diatomite rocks unique properties and lower the viscosity of the oil. Some companies used...

  6. Integrated reservoir characterization for the Mazari oil field, Pakistan 

    E-Print Network [OSTI]

    Ashraf, Ejaz

    1994-01-01

    This thesis describes a field study performed on the Mazari oil field located in Sind province, Pakistan. We used an integrated reservoir characterization technique to incorporate the geological, petrophysical, and reservoir performance data...

  7. Modeling of Magnetic Nanoparticles Transport in Shale Reservoirs 

    E-Print Network [OSTI]

    An, Cheng

    2014-12-18

    stimulated reservoir volume (SRV) from induced fractures play a critical role in significantly increasing well productivity. In this project, a mathematical model for simulating nanoparticle transport in shale reservoirs was developed. The simulator includes...

  8. Evaluating human fecal contamination sources in Kranji Reservoir Catchment, Singapore

    E-Print Network [OSTI]

    Nshimyimana, Jean Pierre

    2010-01-01

    Singapore government through its Public Utilities Board is interested in opening Kranji Reservoir to recreational use. However, water courses within the Kranji Reservoir catchment contain human fecal indicator bacteria ...

  9. Optimal reservoir management using adaptive reduced-order models

    E-Print Network [OSTI]

    Alghareeb, Zeid M

    2015-01-01

    Reservoir management and decision-making is often cast as an optimization problem where we seek to maximize the field's potential recovery while minimizing associated operational costs. Two reservoir management aspects are ...

  10. Structural Reliability: Assessing the Condition and Reliability of Casing in Compacting Reservoirs 

    E-Print Network [OSTI]

    Chantose, Prasongsit

    2012-02-14

    Casing has a higher risk of failure in a compacting reservoir than in a typical reservoir. Casing fails when reservoir compaction induces compression and shear stresses onto it. They compact as reservoir pressure depletes during production. High...

  11. Incorporating reservoir heterogeneity with geostatistics to investigate waterflood recoveries

    SciTech Connect (OSTI)

    Wolcott, D.S. ); Chopra, A.K. )

    1993-03-01

    This paper presents an investigation of infill drilling performance and reservoir continuity with geostatistics and a reservoir simulator. The geostatistical technique provides many possible realizations and realistic descriptions of reservoir heterogeneity. Correlation between recovery efficiency and thickness of individual sand subunits is shown. Additional recovery from infill drilling results from thin, discontinuous subunits. The technique may be applied to variations in continuity for other sandstone reservoirs.

  12. Development and verification of new semi-analytical methods for the analysis and prediction of gas well performance 

    E-Print Network [OSTI]

    Knowles, Robert Stephen

    1999-01-01

    regarding gas properties (i.e., [] = constant, [] = constant, etc.), which eliminates the need for the pseudopressure and pseudotime functions. In particular, these new solutions should lend themselves to use for the analysis of low pressure gas reservoirs...

  13. A Technical and Economic Study of Completion Techniques In Five Emerging U.S. Gas Shale Plays 

    E-Print Network [OSTI]

    Agrawal, Archna

    2010-07-14

    , energy companies, both majors and independents, are turning to unconventional resources to produce the hydrocarbons required to meet market demand. From coalbed methane to low permeability (tight) gas reservoirs and gas shales, energy companies are making...

  14. Toward Production From Gas Hydrates: Current Status, Assessment of Resources, and Simulation-Based Evaluation of Technology and Potential

    E-Print Network [OSTI]

    Moridis, George J.

    2008-01-01

    at producing gas from this unconventional source be aunconventional energy resources clearly shows that the evolution of gasand gas reservoirs, or even to the large (and rapidly increasing) data-base of information on unconventional

  15. Fourteenth workshop geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

    1989-01-01

    The Fourteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 24--26, 1989. Major areas of discussion include: (1) well testing; (2) various field results; (3) geoscience; (4) geochemistry; (5) reinjection; (6) hot dry rock; and (7) numerical modelling. For these workshop proceedings, individual papers are processed separately for the Energy Data Base.

  16. Innovative MIOR Process Utilizing Indigenous Reservoir Constituents

    SciTech Connect (OSTI)

    Hitzman, D.O.; stepp, A.K.; Dennis, D.M.; Graumann, L.R.

    2003-02-11

    This research program was directed at improving the knowledge of reservoir ecology and developing practical microbial solutions for improving oil production. The goal was to identify indigenous microbial populations which can produce beneficial metabolic products and develop a methodology to stimulate those select microbes with nutrient amendments to increase oil recovery. This microbial technology has the capability of producing multiple oil-releasing agents.

  17. Evolution of analyzing reservoir simulation data

    SciTech Connect (OSTI)

    Phelps, R.E.; Huang, A.Y.

    1994-12-31

    Numerical Reservoir Simulation is routinely used by the petroleum producing companies world-wide as an engineering tool to efficiently manage their hydrocarbon reservoirs. The task of building models with a large number of grid-blocks is not easy, and to analyze the voluminous results produced by such models is even more difficult. This paper discusses the historical evolution of techniques used to analyze reservoir simulation data over the past decade. It outlines how the advancement of workstation technology and the introduction of X-Window System opened up an entirely new way of utilizing mainframe computing power and workstation graphical display capabilities, simultaneously. The paper also discusses Saudi Aramco`s experience in the development of sophisticated reservoir simulation post-processing packages. The need for direct communication between the programmer and end-users to facilitate a user-friendly package is emphasized. A practical example illustrating the benefit of these post-processing packages in the construction and history matching of a large model with approximately 52,000 cells is presented. Savings in manpower and computer resources using current technology are estimated.

  18. Evolution of analyzing reservoir simulation data

    SciTech Connect (OSTI)

    Phelps, R.E.; Huang, A.Y.

    1995-12-01

    Petroleum-producing companies world-wide routinely use numerical reservoir simulation as an engineering tool to manage their hydrocarbon reservoirs efficiently. The task of building models with a large number of gridblocks is not easy, and analyzing the voluminous results produced by such models is even more difficult. This paper discusses the historical evolution of techniques used to analyze reservoir simulation data over the past decade. It outlines how the advancement of workstation technology and the introduction of an X-Window system opened up an entirely new way of using mainframe computing power and workstation graphical display capabilities simultaneously. The paper also discusses Saudi Aramco`s experience in the development of sophisticated reservoir simulation postprocessing packages. The authors emphasize the need for direct communication between the programmer and end users to facilitate a user-friendly package. They present a practical example illustrating the benefit of these postprocessing packages in the construction and history matching of a large model with approximately 52,000 cells. They estimate savings in manpower and computer resources using current technology.

  19. Fourteenth workshop geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

    1989-12-31

    The Fourteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 24--26, 1989. Major areas of discussion include: (1) well testing; (2) various field results; (3) geoscience; (4) geochemistry; (5) reinjection; (6) hot dry rock; and (7) numerical modelling. For these workshop proceedings, individual papers are processed separately for the Energy Data Base.

  20. Network Stochastic Programming for Valuing Reservoir Storage

    E-Print Network [OSTI]

    complicates the simultaneous optimization of hydropower for a multi-stage, multi-reservoir system. The expected value of hydropower must be simultaneously optimized over all time steps and scenarios. Previous stochastic programming model of the Tennessee River Basin converged rapidly to an upper bound on hydropower

  1. A Reservoir Sampling Algorithm with Adaptive Estimation of Conditional Expectation

    E-Print Network [OSTI]

    Vucetic, Slobodan

    a reservoir with capacity to hold R examples, the simplest procedure [4] is to replace the t-th observed example from a stream with a randomly chosen reservoir example with probability min(1, R examples, other than the R examples included in the reservoir, are simply ignored. Manuscript received

  2. Petro-electric modeling for CSEM reservoir characterization and monitoring

    E-Print Network [OSTI]

    Key, Kerry

    saturation assuming a noncompacting isothermal reservoir. Time-lapse CSEM has been considered by severalPetro-electric modeling for CSEM reservoir characterization and monitoring Alireza Shahin1 , Kerry to highlight the applicability of this technique for reservoir monitoring. This work appraises the ability

  3. WestVirginiaUniversity SPE 65675 Reservoir Characterization

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    to measure effective porosity (MPHI) and irreducible water saturation (MBVI) in the reservoir rockWestVirginiaUniversity SPE 65675 SPE 65675 Reservoir Characterization Through Synthetic Logs Shahab cost effective way for reservoir characterization. · The methodology uses the available well log data

  4. APPLICATION OF NEW SEISMIC ATTRIBUTES TO RESERVOIR MONITORING

    E-Print Network [OSTI]

    APPLICATION OF NEW SEISMIC ATTRIBUTES TO RESERVOIR MONITORING by Tagir Galikeev #12;#12;ABSTRACT and to best conduct seismic inversion and adapt it to reservoir model building for volumetric computation and reservoir simulation. The author develops algorithms of the seismic attributes including frequency

  5. The Statistical Reservoir Model: calibrating faults and fractures, and predicting reservoir response to water flood

    E-Print Network [OSTI]

    geomechanics to have a significant influence on hydrocarbon production rates through changes in the effective 2004). Geomechanics not only predicts a reservoir response in the near field, but also at long range i

  6. Seismic Determination of Reservoir Heterogeneity: Application to the Characterization of Heavy Oil Reservoirs

    SciTech Connect (OSTI)

    Imhof, Matthias G.; Castle, James W.

    2003-03-12

    The objective of the project was to examine how seismic and geologic data could be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study was performed at West Coalinga Field in California.

  7. Type curve analysis for naturally fractured reservoirs (infinite-acting reservoir case): a new approach 

    E-Print Network [OSTI]

    Angel Restrepo, Juan Alejandro

    2000-01-01

    . The objectives of this work are as follows: First, we generated new type curves for the analysis of pressure drawdown and buildup tests performed in naturally fractured reservoirs. Next, we develop a systematic approach for the analysis and interpretation...

  8. Development of an analytical solution for thermal single-well injection-withdrawal tests in horizontally fractured reservoirs

    E-Print Network [OSTI]

    Jung, Y.

    2014-01-01

    I. (2005), Geothermal Reservoir Characterization via Thermalfor characterization of fractured geothermal reservoirs. For

  9. Development of Reservoir Characterization Techniques and Production Models for Exploiting Naturally Fractured Reservoirs

    SciTech Connect (OSTI)

    Wiggins, Michael L; Brown, Raymon L.; Civan, Faruk; Hughes, Richard G.

    2002-10-08

    During this reporting period, research was continued on characterizing and modeling the behavior of naturally fractured reservoir systems. This report proposed a model to relate the seismic response to production data to determine crack spacing and aperture, provided details of tests of proposed models to obtain fracture properties from conventional well logs with actual field data, and verification of the naturally fractured reservoir simulator developed in this project.

  10. Increasing Waterflood Reserves in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Clarke, D.; Koerner, R.; Moos D.; Nguyen, J.; Phillips, C.; Tagbor, K.; Walker, S.

    1999-04-05

    This project used advanced reservoir characterization tools, including the pulsed acoustic cased-hole logging tool, geologic three-dimensional (3-D) modeling software, and commercially available reservoir management software to identify sands with remaining high oil saturation following waterflood. Production from the identified high oil saturated sands was stimulated by recompleting existing production and injection wells in these sands using conventional means as well as a short radius redrill candidate.

  11. Optimizing Fracture Treatments in a Mississippian "Chat" Reservoir, South-Central Kansas

    SciTech Connect (OSTI)

    K. David Newell; Saibal Bhattacharya; Alan Byrnes; W. Lynn Watney; Willard Guy

    2005-10-01

    This project is a collaboration of Woolsey Petroleum Corporation (a small independent operator) and the Kansas Geological Survey. The project will investigate geologic and engineering factors critical for designing hydraulic fracture treatments in Mississippian ''chat'' reservoirs. Mississippian reservoirs, including the chat, account for 159 million m3 (1 billion barrels) of the cumulative oil produced in Kansas. Mississippian reservoirs presently represent {approx}40% of the state's 5.6*106m3 (35 million barrels) annual production. Although geographically widespread, the ''chat'' is a heterogeneous reservoir composed of chert, cherty dolomite, and argillaceous limestone. Fractured chert with micro-moldic porosity is the best reservoir in this 18- to 30-m-thick (60- to 100-ft) unit. The chat will be cored in an infill well in the Medicine Lodge North field (417,638 m3 [2,626,858 bbls] oil; 217,811,000 m3 [7,692,010 mcf] gas cumulative production; discovered 1954). The core and modern wireline logs will provide geological and petrophysical data for designing a fracture treatment. Optimum hydraulic fracturing design is poorly defined in the chat, with poor correlation of treatment size to production increase. To establish new geologic and petrophysical guidelines for these treatments, data from core petrophysics, wireline logs, and oil-field maps will be input to a fracture-treatment simulation program. Parameters will be established for optimal size of the treatment and geologic characteristics of the predicted fracturing. The fracturing will be performed and subsequent wellsite tests will ascertain the results for comparison to predictions. A reservoir simulation program will then predict the rate and volumetric increase in production. Comparison of the predicted increase in production with that of reality, and the hypothetical fracturing behavior of the reservoir with that of its actual behavior, will serve as tests of the geologic and petrophysical characterization of the oil field. After this feedback, a second well will be cored and logged, and procedure will be repeated to test characteristics determined to be critical for designing cost-effective fracture treatments. Most oil and gas production in Kansas, and that of the Midcontinent oil industry, is dominated by small companies. The overwhelming majority of these independent operators employ less than 20 people. These companies have limited scientific and engineering expertise and they are increasingly needing guidelines and technical examples that will help them to not be wasteful of their limited financial resources and petroleum reserves. To aid these operators, the technology transfer capabilities of the Kansas Geological Survey will disseminate the results of this study to the local, regional, and national oil industry. Internet access, seminars, presentations, and publications by Woolsey Petroleum Company and Kansas Geological Survey geologists and engineers are anticipated.

  12. Ground movements associated with gas hydrate production. Final report

    SciTech Connect (OSTI)

    Siriwardane, H.J.; Kutuk, B.

    1992-03-01

    This report deals with a study directed towards a modeling effort on production related ground movements and subsidence resulting from hydrate dissociation. The goal of this research study was to evaluate whether there could be subsidence related problems that could be an impediment to hydrate production. During the production of gas from a hydrate reservoir, it is expected that porous reservoir matrix becomes more compressible which may cause reservoir compression (compaction) under the influence of overburden weight. The overburden deformations can propagate its influence upwards causing subsidence near the surface where production equipment will be located. In the present study, the reservoir compaction is modeled by using the conventional ``stress equilibrium`` approach. In this approach, the overburden strata move under the influence of body force (i.e. self weight) in response to the ``cavity`` generated by reservoir depletion. The present study is expected to provide a ``lower bound`` solution to the subsidence caused by hydrate reservoir depletion. The reservoir compaction anticipated during hydrate production was modeled by using the finite element method, which is a powerful computer modeling technique. The ground movements at the reservoir roof (i.e. reservoir compression) cause additional stresses and disturbance in the overburden strata. In this study, the reservoir compaction was modeled by using the conventional ``stress equilibrium`` approach. In this approach, the overburden strata move under the influence of body force (i.e. self weight) in response to the ``cavity`` generated by reservoir depletion. The resulting stresses and ground movements were computed by using the finite element method. Based on the parameters used in this investigation, the maximum ground subsidence could vary anywhere from 0.50 to 6.50 inches depending on the overburden depth and the size of the depleted hydrate reservoir.

  13. US crude oil, natural gas, and natural gas liquids reserves, 1992 annual report

    SciTech Connect (OSTI)

    Not Available

    1993-10-18

    This report presents estimates of proved reserves of crude oil, natural gas, and natural gas liquids as of December 31, 1992, as well as production volumes for the United States, and selected States and State subdivisions for the year 1992. Estimates are presented for the following four categories of natural gas: total gas (wet after lease separation), its two major components (nonassociated and associated-dissolved gas), and total dry gas (wet gas adjusted for the removal of liquids at natural gas processing plants). In addition, two components of natural gas liquids, lease condensate and natural gas plant liquids, have their reserves and production data presented. Also included is information on indicated additional crude oil reserves and crude oil, natural gas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1992 is provided.

  14. Environment of deposition and reservoir properties of Teapot sandstones (Upper Cretaceous), Well Draw field, Converse County, Wyoming 

    E-Print Network [OSTI]

    Sullivan, John Joseph

    1982-01-01

    fossils, and reservoir morphology. Three distinct sandstone facies produce oil and gas at Well Draw field. The main producing zone consists of thicker, channel turbidites. The lower two zones are thinly interbedded with shale and have limited reservoir... to oil ratio was 900 cu ft/bbl (Isbell et al, , 1976). Temperatures within Teapot sandstones yield an average geothermal gradient of 1, 21'F/100 ft (22. 0'C/km). More than 350 wells were drilled on 160 acre spacing in the Well Draw area...

  15. Reservoir analysis study, Naval Petroleum Reserve No. 1, Elk Hills Field, Kern County, California: Phase 2 report: Volume 2

    SciTech Connect (OSTI)

    Not Available

    1988-06-01

    The objectives for this Phase II study included the establishment of revised estimates of the original oil and gas-in-place for each of the zones/reservoirs, estimation of the remaining proved developed, proved undeveloped, probable and possible reserves, and assessment of the effects of historical development and production operations and practices on recoverable reserves. Volume two contains reservoir studies for: Stevens/endash/26R/2B; Stevens/endash/29R242/132/Asphalto; Stevens/endash/Northwest; and Carneros.

  16. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2001-10-01

    The main objectives of the proposed study are as follows: (1) To understand and evaluate an unusual primary oil production mechanism which results in decreasing (retrograde) oil cut (ROC) behavior as reservoir pressure declines. (2) To develop better, produced water, disposal techniques so as to minimize lifting costs, surface separation costs and water disposal costs. (3) To improve calculations of initial oil in place so as to determine the economic feasibility of completing and producing a well. (4) To optimize the location of new wells based on understanding of geological and petrophysical properties heterogeneities. (5) To evaluate various secondary recovery techniques for oil reservoirs producing from fractured formations. (6) To enhance the productivity of producing wells by using new completion techniques. These objectives are important for optimizing field performance from West Carney Field located in Lincoln County, Oklahoma. The field, which was discovered in 1980, produces from Hunton Formation in a shallow-shelf carbonate reservoir. The early development in the field was sporadic. Many of the initial wells were abandoned due to high water production and constraints in surface facilities for disposing excess produced water. The field development began in earnest in 1995 by Altex Resources. They had recognized that production from this field was only possible if large volumes of water can be disposed. Being able to dispose large amounts of water, Altex aggressively drilled several producers. With few exceptions, all these wells exhibited similar characteristics. The initial production indicated trace amount of oil and gas with mostly water as dominant phase. As the reservoir was depleted, the oil cut eventually improved, making the overall production feasible. The decreasing oil cut (ROC) behavior has not been well understood. However, the field has been subjected to intense drilling activity because of prior success of Altex Resources. In this work, we will investigate the primary production mechanism by conducting several core flood experiments. After collecting cores from representative wells, we will study the wettability of the rock and simulate the depletion behavior by mimicking such behavior under controlled lab conditions. The overall project goal would be to validate our hypothesis and to determine the best method to exploit reservoirs exhibiting ROC behavior. To that end, we will collect and analyze core samples, and run a single well tracer test during the Budget Period I. We will continue to drill vertical wells during this period. Once we understand the mechanism and are able to quantify the geological model, in Budget Period II we will drill several, additional wells. Depending on the feasibility, we will equip some of the vertical wells with downhole separator, as well as surface compact separator. This will allow us to compare the new technology with the existing one. In the Budget Period III, we will monitor the field performance and revise and refine our models to further optimize the performance.

  17. ALKALINE-SURFACTANT-POLYMER FLOODING AND RESERVOIR CHARACTERIZATION OF THE BRIDGEPORT AND CYPRESS RESERVOIRS OF THE LAWRENCE FIELD

    SciTech Connect (OSTI)

    Malcolm Pitts; Ron Damm; Bev Seyler

    2003-04-01

    Feasibility of alkaline-surfactant-polymer flood for the Lawrence Field in Lawrence County, Illinois is being studied. Two injected formulations are being designed; one for the Bridgeport A and Bridgeport B reservoirs and one for Cypress and Paint Creek reservoirs. Fluid-fluid and coreflood evaluations have developed a chemical solution that produces incremental oil in the laboratory from the Cypress and Paint Creek reservoirs. A chemical formulation for the Bridgeport A and Bridgeport B reservoirs is being developed. A reservoir characterization study is being done on the Bridgeport A, B, & D sandstones, and on the Cypress sandstone. The study covers the pilot flood area and the Lawrence Field.

  18. ALKALINE-SURFACTANT-POLYMER FLOODING AND RESERVOIR CHARACTERIZATION OF THE BRIDGEPORT AND CYPRESS RESERVOIRS OF THE LAWRENCE FIELD

    SciTech Connect (OSTI)

    Malcolm Pitts; Ron Damm; Bev Seyler

    2003-03-01

    Feasibility of alkaline-surfactant-polymer flood for the Lawrence Field in Lawrence County, Illinois is being studied. Two injected formulations are being designed; one for the Bridgeport A and Bridgeport B reservoirs and one for Cypress and Paint Creek reservoirs. Fluid-fluid and coreflood evaluations have developed a chemical solution that produces incremental oil in the laboratory from the Cypress and Paint Creek reservoirs. A chemical formulation for the Bridgeport A and Bridgeport B reservoirs is being developed. A reservoir characterization study is being done on the Bridgeport A, B, & D sandstones, and on the Cypress sandstone. The study covers the pilot flood area and the Lawrence Field.

  19. UDC 622.276 A NEW APPROACH CALCULATE OIL-GAS RATIO

    E-Print Network [OSTI]

    Fernandez, Thomas

    UDC 622.276 A NEW APPROACH CALCULATE OIL-GAS RATIO FOR GAS CONDENSATE AND VOLATILE OIL RESERVOIRS. In this work, we develop a new approach to calculate oil-gas ratio (Rv) by matching PVT experimental data laboratory analysis of eight gas condensate and five volatile oil fluid samples; selected under a wide range

  20. Gas-assisted gravity drainage (GAGD) process for improved oil recovery

    DOE Patents [OSTI]

    Rao, Dandina N. (Baton Rouge, LA)

    2012-07-10

    A rapid and inexpensive process for increasing the amount of hydrocarbons (e.g., oil) produced and the rate of production from subterranean hydrocarbon-bearing reservoirs by displacing oil downwards within the oil reservoir and into an oil recovery apparatus is disclosed. The process is referred to as "gas-assisted gravity drainage" and comprises the steps of placing one or more horizontal producer wells near the bottom of a payzone (i.e., rock in which oil and gas are found in exploitable quantities) of a subterranean hydrocarbon-bearing reservoir and injecting a fluid displacer (e.g., CO.sub.2) through one or more vertical wells or horizontal wells. Pre-existing vertical wells may be used to inject the fluid displacer into the reservoir. As the fluid displacer is injected into the top portion of the reservoir, it forms a gas zone, which displaces oil and water downward towards the horizontal producer well(s).

  1. Innovative MIOR Process Utilizing Indigenous Reservoir Constituents

    SciTech Connect (OSTI)

    D. O. Hitzman; A. K. Stepp; D. M. Dennis; L. R. Graumann

    2003-03-31

    This research program is directed at improving the knowledge of reservoir ecology and developing practical microbial solutions for improving oil production. The goal is to identify indigenous microbial populations which can produce beneficial metabolic products and develop a methodology to stimulate those select microbes with nutrient amendments to increase oil recovery. This microbial technology has the capability of producing multiple oil-releasing agents. Experimental laboratory work is underway. Microbial cultures have been isolated from produced water samples. Comparative laboratory studies demonstrating in situ production of microbial products as oil recovery agents were conducted in sand packs with natural field waters with cultures and conditions representative of oil reservoirs. Field pilot studies are underway.

  2. Exploitation and Optimization of Reservoir Performance in Hunton Formation, Oklahoma

    SciTech Connect (OSTI)

    Mohan Kelkar

    2005-10-01

    West Carney field--one of the newest fields discovered in Oklahoma--exhibits many unique production characteristics. These characteristics include: (1) decreasing water-oil ratio; (2) decreasing gas-oil ratio followed by an increase; (3) poor prediction capability of the reserves based on the log data; and (4) low geological connectivity but high hydrodynamic connectivity. The purpose of this investigation is to understand the principal mechanisms affecting the production, and propose methods by which we can extend the phenomenon to other fields with similar characteristics. In our experimental investigation section, we continue to describe the use of surfactant to alter the wettability of the rock. By altering the wettability, we should be able to change the water-gas ratio in the reservoir and, hence, improve productivity from the well. In our Engineering and Geological Analysis section, we present our rock typing analysis work which combines the geological data with engineering data to develop a unique rock characteristics description. By using porosity as a variable, we can generate alternate rock type descriptions at logged wells. This procedure also allows us to quantify uncertainties in rock type description.

  3. Model for locating fluids` contracts in petroleum reservoirs

    SciTech Connect (OSTI)

    Udegbunam, E.O. [Illinois State Geological Survey, Champaign, IL (United States); Numbere, D.T. [Univ. of Missouri, Rolla, MO (United States)

    1994-12-31

    Direct determination of the gas-water contact (GWC) or the oil-water contact (OWC) in new wells from geophysical logs, core analysis data and/or whole core inspection is often difficult. Rapidly changing reservoir quality in the interval of interest or gradually changing saturation profiles in the vicinity of the contact can make the determination of the GWC or OWC difficult. This paper presents a model for the accurate placement of the GWC or OWC. The input data are water saturations at various well depths as interpreted from induction logs and the average residual oil saturation. When available, permeability and porosity values from core analysis may improve the result. Using a power-law equation or a Langmuir isotherm-type equation to represent the capillary pressure saturation relationship, the GWC or OWC is expressed as a function of water saturation and well depth. A nonlinear optimization technique is then used to determine the GWC or OWC. The applicability of this model is demonstrated with a field example. The calculated OWC values from all variations of the model fall within 4 feet of the actual OWC value. This model can only be applied in an oil or gas well where an equilibrium capillary curve and a hydrocarbon-water contact occur.

  4. RESERVOIR CHARACTERIZATION OF UPPER DEVONIAN GORDON SANDSTONE, JACKSONBURG STRINGTOWN OIL FIELD, NORTHWESTERN WEST VIRGINIA

    SciTech Connect (OSTI)

    S. Ameri; K. Aminian; K.L. Avary; H.I. Bilgesu; M.E. Hohn; R.R. McDowell; D.L. Matchen

    2001-07-01

    The Jacksonburg-Stringtown oil field contained an estimated 88,500,000 barrels of oil in place, of which approximately 20,000,000 barrels were produced during primary recovery operations. A gas injection project, initiated in 1934, and a pilot waterflood, begun in 1981, yielded additional production from limited portions of the field. The pilot was successful enough to warrant development of a full-scale waterflood in 1990, involving approximately 8,900 acres in three units, with a target of 1,500 barrels of oil per acre recovery. Historical patterns of drilling and development within the field suggests that the Gordon reservoir is heterogeneous, and that detailed reservoir characterization is necessary for understanding well performance and addressing problems observed by the operators. The purpose of this work is to establish relationships among permeability, geophysical and other data by integrating geologic, geophysical and engineering data into an interdisciplinary quantification of reservoir heterogeneity as it relates to production. Conventional stratigraphic correlation and core description shows that the Gordon sandstone is composed of three parasequences, formed along the Late Devonian shoreline of the Appalachian Basin. The parasequences comprise five lithofacies, of which one includes reservoir sandstones. Pay sandstones were found to have permeabilities in core ranging from 10 to 200 mD, whereas non-pay sandstones have permeabilities ranging from below the level of instrumental detection to 5 mD; Conglomeratic zones could take on the permeability characteristics of enclosing materials, or could exhibit extremely low values in pay sandstone and high values in non-pay or low permeability pay sandstone. Four electrofacies based on a linear combination of density and scaled gamma ray best matched correlations made independently based on visual comparison of geophysical logs. Electrofacies 4 with relatively high permeability (mean value > 45 mD) was determined to be equivalent to the pay sandstone within the Gordon reservoir. Three-dimensional models of the electrofacies in the pilot waterflood showed that electrofacies 4 is present throughout this area, and the other electrofacies are more disconnected. A three-layer, back-propagation artificial neural network with three slabs in the middle layer can be used to predict permeability and porosity from gamma ray and bulk density logs, the first and the second derivatives of the log data with respect to depth, well location, and log baselines. Two flow units were defined based on the stratigraphic model and geophysical logs. A three-dimensional reservoir model including the flow units, values of permeability calculated through the artificial neural network and injection pressure-rate information were then used as inputs for a reservoir simulator to predict oil production performance for the center producers in the pilot area. This description of the reservoir provided significantly better simulation results than earlier results obtained using simple reservoir models. Bulk density and gamma ray logs were used to identify flow units throughout the field. As predicted by the stratigraphic analysis, one of the flow units crosses stratigraphic units in the reservoir. A neural network was used to predict permeability values for each flow unit in producer and injection wells. The reservoir simulator was utilized to predict the performance of two flood patterns located to the north of the pilot area. Considering the simple model utilized for simulation, the results are in very good agreement with the field history.

  5. Innovative MIOR Process Utilizing Indigenous Reservoir Constituents

    SciTech Connect (OSTI)

    Hitzman, D.O.; Stepp, A.K.; Dennis, D.M.; Graumann, L.R.

    2003-02-11

    This research program was directed at improving the knowledge of reservoir ecology and developing practical microbial solutions for improving oil production. The goal was to identify indigenous microbial populations which can produce beneficial metabolic products and develop a methodology to stimulate those select microbes with inorganic nutrient amendments to increase oil recovery. This microbial technology has the capability of producing multiple oil-releasing agents.

  6. Full Reviews: Reservoir Characterization | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious Rank EERE:FinancingPetroleum12, 2015ExecutiveFluorescentDanKathy gdr.openei.orgReservoir Characterization

  7. Application of turbidite facies of the Stevens Oil Zone for reservoir management, Elk Hills Field, California

    SciTech Connect (OSTI)

    Reid, S.A.; Thompson, T.W.; McJannet, G.S.

    1996-12-31

    A detailed depositional model for the uppermost sand reservoirs of the Stevens Oil Zone, Elk Hills Field, California, contains three facies: turbidite channel-fill sand bodies, overbank Sandstone and mudstone, and pelagic and hemipelagic siliceous shale. Sand bodies are the primary producing facies and consist of layered, graded sandstone with good permeability. The presence of incipient anticlines with subsea relief in the late Miocene resulted in deposition of lenticular and sinuous sand Was within structurally created channels. Relief of these structural channels was low when the earliest sand bodies were deposited, leading to a wide channel complex bounded by broad overbank deposits of moderate to low permeability. As deposition proceeded, increased structural relief constrained the channels, resulting in narrower sand body width and relatively abrupt channel terminations against very low permeability siliceous shale. With post-Miocene uplift and differential compaction, stratigraphic mounding of sand bodies helped create structural domes such as the 24Z reservoir. Stratigraphic traps including the 26R reservoir were also created. Such traps vary in seal quality from very effective to leaky, depending on the lateral transition from sand bodies to siliceous shale. Application of the Elk Hills turbidity model (1) provides a framework for monitoring production performance in the 24Z and Northwest Stevens waterflood projects; and for tracking gas migration into and out of the 26R reservoir, (2) helps b identify undeveloped locations in the 26R reservoir ideally suited for horizontal wells, (3) has led to the identification of two new production trends in the 29R area, and (4) makes possible the development of exploration plays in western Elk Hills.

  8. Application of turbidite facies of the Stevens Oil Zone for reservoir management, Elk Hills Field, California

    SciTech Connect (OSTI)

    Reid, S.A.; Thompson, T.W. ); McJannet, G.S. )

    1996-01-01

    A detailed depositional model for the uppermost sand reservoirs of the Stevens Oil Zone, Elk Hills Field, California, contains three facies: turbidite channel-fill sand bodies, overbank Sandstone and mudstone, and pelagic and hemipelagic siliceous shale. Sand bodies are the primary producing facies and consist of layered, graded sandstone with good permeability. The presence of incipient anticlines with subsea relief in the late Miocene resulted in deposition of lenticular and sinuous sand Was within structurally created channels. Relief of these structural channels was low when the earliest sand bodies were deposited, leading to a wide channel complex bounded by broad overbank deposits of moderate to low permeability. As deposition proceeded, increased structural relief constrained the channels, resulting in narrower sand body width and relatively abrupt channel terminations against very low permeability siliceous shale. With post-Miocene uplift and differential compaction, stratigraphic mounding of sand bodies helped create structural domes such as the 24Z reservoir. Stratigraphic traps including the 26R reservoir were also created. Such traps vary in seal quality from very effective to leaky, depending on the lateral transition from sand bodies to siliceous shale. Application of the Elk Hills turbidity model (1) provides a framework for monitoring production performance in the 24Z and Northwest Stevens waterflood projects; and for tracking gas migration into and out of the 26R reservoir, (2) helps b identify undeveloped locations in the 26R reservoir ideally suited for horizontal wells, (3) has led to the identification of two new production trends in the 29R area, and (4) makes possible the development of exploration plays in western Elk Hills.

  9. Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia

    SciTech Connect (OSTI)

    Luthy, S.T. [Saudi Aramco, Dhahran (Saudi Arabia)

    1996-12-31

    Fractures play a significant role in the transmissibility of the Hanifa reservoir at Abqaiq Field. The Hanifa is a Type 2 fractured reservoir characterized by a finely-crystalline carbonate matrix which contains most of the reservoir storage porosity, and a stylolitic fracture system which provides essential permeability. Comparisons of over 5000 fractures identified from core and borehole image data with open-hole log data showed that porosity is negatively correlated with fracture density and mechanical rock strength. From these relationships, it was possible to utilize additional wells where porosity log data was available to calculate fracture densities. These wells were used to generate matrix porosity and permeability as well as fracture density attributes in a 12-sequence, 29-layer geocellular model. The effect of structural curvature on fracture intensity in the reservoir was estimated by mapping the derivative of structural dip. Incorporation of structural curvature explained variations in well test behavior not predicted by initial estimates of fracture density from porosity alone. Resultant fracture permeabilities compared favorably with well-test derived productivity indices. Three-dimensional visualization of model attributes showed that a monotonous and low (<10 md) distribution of matrix-related permeability contrasts sharply with highly variable and relatively high (>50 md) permeabilities of the fracture system. Reliability of the geocellular model to predict fracture densities and associated permeabilities has been confirmed by subsequent drilling of high cost horizontal wells, and is being used in reservoir engineering and development drilling planning efforts.

  10. Dual-porosity reservoir modeling of the fractured Hanifa reservoir, Abqaiq Field, Saudi Arabia

    SciTech Connect (OSTI)

    Luthy, S.T. (Saudi Aramco, Dhahran (Saudi Arabia))

    1996-01-01

    Fractures play a significant role in the transmissibility of the Hanifa reservoir at Abqaiq Field. The Hanifa is a Type 2 fractured reservoir characterized by a finely-crystalline carbonate matrix which contains most of the reservoir storage porosity, and a stylolitic fracture system which provides essential permeability. Comparisons of over 5000 fractures identified from core and borehole image data with open-hole log data showed that porosity is negatively correlated with fracture density and mechanical rock strength. From these relationships, it was possible to utilize additional wells where porosity log data was available to calculate fracture densities. These wells were used to generate matrix porosity and permeability as well as fracture density attributes in a 12-sequence, 29-layer geocellular model. The effect of structural curvature on fracture intensity in the reservoir was estimated by mapping the derivative of structural dip. Incorporation of structural curvature explained variations in well test behavior not predicted by initial estimates of fracture density from porosity alone. Resultant fracture permeabilities compared favorably with well-test derived productivity indices. Three-dimensional visualization of model attributes showed that a monotonous and low (<10 md) distribution of matrix-related permeability contrasts sharply with highly variable and relatively high (>50 md) permeabilities of the fracture system. Reliability of the geocellular model to predict fracture densities and associated permeabilities has been confirmed by subsequent drilling of high cost horizontal wells, and is being used in reservoir engineering and development drilling planning efforts.

  11. Effects of diagenesis on reservoir quality within two Cypress reservoirs in the Illinois basin

    SciTech Connect (OSTI)

    Scott, B.D.; McGee, K.R.; Seyler, B. (Illinois State Geological Survey, Champaign (United States))

    1991-08-01

    One billion bbl of oil have been produced from the Chesterian Cypress Formation in the Illinois basin. These heterogeneous reservoirs may consist of deltaic, marine-reworked deltaic, and/or reworked marine sandstone within mixed siliciclastic-carbonate environments. Thin section, x-ray diffraction, and scanning electron microscopy coupled with energy dispersive x-ray analysis indicate that the effects of diagenesis play a significant role in reservoir quality of Mattoon and Parkersburg fields in Illinois. Five separate Cypress sandstones may be present at Mattoon field (Coles County), a predominantly stratigraphic trap, produces from three distinct Cypress strata. In these fields, reservoir quality is reduced when quartz overgrowths and later stage, blocky mosaic ferroan-calcite cement occlude pore throats. Authigenic clay minerals occur as pore-lining particles that inhibit fluid-flow. Clay minerals preset are illite, mixed-layered illite/smectite, chlorite, and kaolinite. Reservoir quality is enhanced through dissolution of early ferroan-calcite cement, dissolution of detrital feldspar, and microfracturing. Completion, stimulation, and production programs within the heterogeneous Cypress sandstone reservoirs would be improved by recognition of mineral relationships and diagenetic overprints. Developments programs may need to include the use of clay stabilizers in mud clean-out acid treatments.

  12. T-R Cycle Characterization and Imaging: Advanced Diagnostic Methodology for Petroleum Reservoir and Trap Detection and Delineation

    SciTech Connect (OSTI)

    Ernest A. Mancini

    2006-08-30

    Characterization of stratigraphic sequences (T-R cycles or sequences) included outcrop studies, well log analysis and seismic reflection interpretation. These studies were performed by researchers at the University of Alabama, Wichita State University and McGill University. The outcrop, well log and seismic characterization studies were used to develop a depositional sequence model, a T-R cycle (sequence) model, and a sequence stratigraphy predictive model. The sequence stratigraphy predictive model developed in this study is based primarily on the modified T-R cycle (sequence) model. The T-R cycle (sequence) model using transgressive and regressive systems tracts and aggrading, backstepping, and infilling intervals or sections was found to be the most appropriate sequence stratigraphy model for the strata in the onshore interior salt basins of the Gulf of Mexico to improve petroleum stratigraphic trap and specific reservoir facies imaging, detection and delineation. The known petroleum reservoirs of the Mississippi Interior and North Louisiana Salt Basins were classified using T-R cycle (sequence) terminology. The transgressive backstepping reservoirs have been the most productive of oil, and the transgressive backstepping and regressive infilling reservoirs have been the most productive of gas. Exploration strategies were formulated using the sequence stratigraphy predictive model and the classification of the known petroleum reservoirs utilizing T-R cycle (sequence) terminology. The well log signatures and seismic reflector patterns were determined to be distinctive for the aggrading, backstepping and infilling sections of the T-R cycle (sequence) and as such, well log and seismic data are useful for recognizing and defining potential reservoir facies. The use of the sequence stratigraphy predictive model, in combination with the knowledge of how the distinctive characteristics of the T-R system tracts and their subdivisions are expressed in well log patterns and seismic reflection configurations and terminations, improves the ability to identify and define the limits of potential stratigraphic traps and the stratigraphic component of combination stratigraphic and structural traps and the associated continental, coastal plain and marine potential reservoir facies. The assessment of the underdeveloped and undiscovered reservoirs and resources in the Mississippi Interior and North Louisiana Salt Basins resulted in the confirmation of the Monroe Uplift as a feature characterized by a major regional unconformity, which serves as a combination stratigraphic and structural trap with a significant stratigraphic component, and the characterization of a developing play in southwest Alabama, which involves a stratigraphic trap, located updip near the pinchout of the potential reservoir facies. Potential undiscovered and underdeveloped reservoirs in the onshore interior salt basins are identified as Jurassic and Cretaceous aggrading continental and coastal, backstepping nearshore marine and marine shelf, and infilling fluvial, deltaic, coastal plain and marine shelf.

  13. Simulation studies to evaluate the effect of fracture closure on the performance of naturally fractured reservoirs. Annual report

    SciTech Connect (OSTI)

    Not Available

    1992-11-01

    The second year of this three-year research program to evaluate the effect of fracture closure on the recovery of oil and gas from naturally fractured reservoirs has been completed. The overall objectives of the study are to: (1) evaluate the reservoir conditions where fracture closure is significant, and (2) evaluate innovative fluid injection techniques capable of maintaining pressure within the reservoir. Simulation studies have been conducted with a dual porosity simulator capable of simulating the performance of vertical and horizontal wells. Each simulation model has been initialized with properties typical of the Austin Chalk reservoir in Pearsall Field, Texas. During year one, simulations of both vertical and horizontal well performance were made assuming that fracture permeability was insensitive to pressure charge. The results confirmed that horizontal wells could increase both rate of oil recovery and total oil recovery from naturally fractured reservoirs. During the second year the performances of the same vertical and horizontal wells were evaluated with the assumption that fracture permeability was a function of reservoir pressure. This required repetition of most of the natural depletion cases simulated in year one while invoking the pressure-sensitive fracture permeability option. To investigate sensitivity to in situ stress, two stress conditions were simulated for each primary variable. The water injection cases, begun in year one, were extended to include most of the reservoir parameters investigated for natural depletion, including fracture permeability as a function of net stress and the use of horizontal wells. The results thus far confirm that pressure-sensitive fractures degrade well performance and that the degradation is reduced by water injection pressure maintenance. Furthermore, oil recovery can be significantly increased by water injection pressure maintenance.

  14. Smoothing method aids gas-inventory variance trending

    SciTech Connect (OSTI)

    Mason, R.G. )

    1992-03-23

    This paper reports on a method for determining gas-storage inventory and variance in a natural-gas storage field which uses the equations developed to determine gas-in-place in a production field. The calculations use acquired data for shut-in pressures, reservoir pore volume, and storage gas properties. These calculations are then graphed and trends are developed. Evaluating trends in inventory variance can be enhanced by use of a technique, described here, that smooths the peaks and valleys of an inventory-variance curve. Calculations using the acquired data determine inventory for a storage field whose drive mechanism is gas expansion (that is, volumetric). When used for a dry gas, condensate, or gas-condensate reservoir, the formulas require no further modification. Inventory in depleted oil fields can be determined in this same manner, as well. Some additional calculations, however, must be made to assess the influence of oil production on the gas-storage process.

  15. Application of reservoir geology of enhanced oil recovery from upper Devonian Nisku Reefs, Alberta, Canada

    SciTech Connect (OSTI)

    Watts, N.R. (AEC Oil and Gas Company, Calgary, Alberta (Canada)); Coppold, M.P. (Imperial Oil Resources Limited (Esso), Calgary, Alberta (Canada)); Douglas, J.L. (Saudi Aramco, Dhahran (Saudi Arabia))

    1994-01-01

    The Upper Devonian West Pembina reef trend of west-central Alberta contains recoverable reserves of over 79 x 10[sup 6] m[sup 3] (500 million bbl) of oil and 1.4 x 10[sup 10] m[sup 3] (500 billion ft[sup 3]) of gas within approximately 50 pinnacle reefs in the Nisku Formation. Although the oil is saturated with gas at original reservoir pressure, primary depletion would soon lower the reservoir pressure below the bubble point, decreasing recovery. Thus, pressure maintenance is applied early in the producing life of the pools through waterflood or miscible flood schemes. Selection of the appropriate enhanced recovery scheme depends upon the internal flow-unit geometry of the reefs. The Bigoray Nisku C pool and the Pembina Nisku L pool form end members of the reservoir spectrum. They can be used as flow-unit models in the geological input for reservoir simulation studies. The Bigoray Nisku C pool is dominantly limestone. The primary textures, well perserved in this reef, provide the key to interpreting the relict textures in fully dolomitized reefs. Due to the presence of horizontal permeability barriers associated with the limestone lithology, the pool is developed with a waterflood displacement scheme. Ultimate recovery is estimated to be on the order of 0.55 x 10[sup 6] m[sup 3] (3.5 million bbl) or 46% or original oil in place (OOIP). The Pembina Nisku L pool is a completely dolomitized reef. In contrast to the Bigoray Nisku C pool, the complete dolomitization reduces the number of generic reservoir flow units observed in the L pool reef from six to three. Due to the excellent reservoir quality and absence of horizontal permeability barriers, it is being exploited by a vertical miscible flood. The Nisku L pool is one of the largest pinnacle reefs discovered in the Nisku reef fairway and contains an estimated 5 x 10[sup 6] m[sup 3] (31 million bbl) OOIP. Ultimate recovery is estimated to be approximately 4.1 x 10[sup 6] m[sup 3] (25.8 million bbl) or 82% of OOIP.

  16. SEISMIC DETERMINATION OF RESERVOIR HETEROGENEITY: APPLICATION TO THE CHARACTERIZATION OF HEAVY OIL RESERVOIRS

    SciTech Connect (OSTI)

    Matthias G. Imhof; James W. Castle

    2005-02-01

    The objective of the project was to examine how seismic and geologic data can be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study focused on West Coalinga Field in California. The project initially attempted to build reservoir models based on different geologic and geophysical data independently using different tools, then to compare the results, and ultimately to integrate them all. Throughout the project, however, we learned that this strategy was impractical because the different data and model are complementary instead of competitive. For the complex Coalinga field, we found that a thorough understanding of the reservoir evolution through geologic times provides the necessary framework which ultimately allows integration of the different data and techniques.

  17. SEISMIC DETERMINATION OF RESERVOIR HETEROGENEITY: APPLICATION TO THE CHARACTERIZATION OF HEAVY OIL RESERVOIRS

    SciTech Connect (OSTI)

    Matthias G. Imhof; James W. Castle

    2005-02-01

    The objective of the project was to examine how seismic and geologic data can be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study focused on West Coalinga Field in California. The project initially attempted to build reservoir models based on different geologic and geophysical data independently using different tools, then to compare the results, and ultimately to integrate them all. We learned, however, that this strategy was impractical. The different data and tools need to be integrated from the beginning because they are all interrelated. This report describes a new approach to geostatistical modeling and presents an integration of geology and geophysics to explain the formation of the complex Coalinga reservoir.

  18. Potosi Reservoir Modeling; History and Recommendations

    SciTech Connect (OSTI)

    Smith, Valerie; Leetaru, Hannes

    2014-09-30

    As a part of a larger project co-funded by the United States Department of Energy (US DOE) to evaluate the potential of formations within the Cambro-Ordovician strata above the Mt. Simon as potential targets for carbon sequestration in the Illinois and Michigan Basins, the Illinois Clean Coal Institute (ICCI) requested Schlumberger to evaluate the potential injectivity and carbon dioxide (CO?) plume size of the Cambrian Potosi Formation. The evaluation of this formation was accomplished using wireline data, core data, pressure data, and seismic data from two projects: the US DOE-funded Illinois Basin–Decatur Project being conducted by the Midwest Geological Sequestration Consortium in Macon County, Illinois, as well as data from the Illinois – Industrial Carbon Capture and Sequestration (IL-ICCS) project funded through the American Recovery and Reinvestment Act. In 2010, technical performance evaluations on the Cambrian Potosi Formation were performed through reservoir modeling. The data included formation tops from mud logs, well logs from the Verification Well 1 (VW1) and the Injection Well (CCS1), structural and stratigraphic formation from three dimensional (3D) seismic data, and field data from several waste water injection wells for the Potosi Formation. The intention was for two million tonnes per annum (MTPA) of CO? to be injected for 20 years into the Potosi Formation. In 2013, updated reservoir models for the Cambrian Potosi Formation were evaluated. The data included formation tops from mud logs, well logs from the CCS1, VW1, and Verification Well 2 (VW2) wells, structural and stratigraphic formation from a larger 3D seismic survey, and field data from several waste water injection wells for Potosi Formation. The objective is to simulate the injection of CO? at a rate 3.5 million tons per annum (3.2 million tonnes per annum [MTPA]) for 30 years 106 million tons (96 MT total) into the Potosi Formation. The Potosi geomodeling efforts have evolved from using data from a single well in 2010 to the inclusion of data from three wells in 2013 which largely leverage the porosity and permeability logs plus knowledge of lost circulation zones. The first Potosi model (Potosi Geobody Model 2010) attempted to use the available seismic inversion data to inform the geomodel and predict vugular zones in advance of drilling VW1. Lost circulation zones in VW1 came in as the geologists predicted. The model was not implemented in subsequent simulation work. To date, reservoir models used for flow simulation work have relied predominately on Gaussian distributed properties (porosity and permeability) and have employed a single injection well. Potosi Model 2013b incorporated the new VW2 logs, and exhibited an extra level of sophistication by delineating the vugular intervals. This method added further realism that likely represents the best reservoir approximation to date. Where the 2010 reservoir models were 10 by 10 mi (16 by 16 km) in area, the 2013 models were expanded in size to 30 by 30 mi (48 by 48 km). The latest reservoir simulations show that a minimum of four injectors might be required to meet target injection rates. Still, there is data that requires further scrutiny and modeling methodologies that require testing for the Potosi Formation. This work is currently ongoing, and the next phase of the reservoir modeling intends to implement valuable data like porosity derived from seismic inversion, seismically derived geobodies, or a combination of both to further define vugular zones and the porosity distribution within the Potosi Formation. Understanding the dual porosity, dual permeability character of the Potosi remains the greatest challenge in representing this formation. Further analysis of the FMI* fullbore formation microimager data may aid in assessing this uncertainty. The Potosi Formation is indeed an interesting formation, and recommendations to further characterize it are included in the following list: - Data acquisition to identify the vugs permeability, distribution, and interconnectivity could b

  19. Horizontal well replaces hydraulic fracturing in North Sea gas well

    SciTech Connect (OSTI)

    Reynolds, D.A.; Seymour, K.P. )

    1991-11-25

    This paper reports on excessive water production from hydraulically fractured wells in a poor quality reservoir in the North SEa which prompted the drilling of a horizontal well. Gas production from the horizontal well reached six times that of the offset vertical wells, and no water production occurred. This horizontal well proved commercial the western section of the Anglia field. Horizontal drilling in the North SEa is as an effective technology to enhance hydrocarbon recovery from reservoirs that previously had proven uncommercial with other standard techniques. It is viable for the development of marginal reservoirs, particularly where conditions preclude stimulation from hydraulic fracturing.

  20. STABILIZATION OF GAS LIFTED WELLS BASED ON STATE ESTIMATION

    E-Print Network [OSTI]

    Foss, Bjarne A.

    oil and gas from wells with low reservoir pressure by reducing the hydrostatic pressure in the tubing.imsland bjarne.foss}@itk.ntnu.no Abstract: This paper treats stabilization of multiphase flow in a gas lifted oil well. Two different controllers are investigated, PI control using the estimated downhole pressure