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Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- Research Report > New Finding (0.93)
- Overview (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.72)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- (2 more...)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- North America > United States > Texas (1.00)
- Europe (0.93)
- Research Report > New Finding (0.93)
- Overview (0.88)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
Disposable Fibre Optic Surveys Optimise Wells and Reduce CO2 Emissions in Unconventional Assets
Crawford, R. (Well-Sense Technology Ltd, Perth, Australia.) | Green, A. (Well-Sense Technology Ltd, Aberdeen, Scotland.) | Lynch, P. (Well-Sense Technology Ltd, Aberdeen, Scotland.) | Feherty, C. (Well-Sense Technology Ltd, Aberdeen, Scotland.)
Abstract The large quantity of batch wells typical in unconventional fields results in per well incremental optimisation gains compounding and significantly improving asset economics. A disposable, cost effective, fibre optic intervention system safely and efficiently provides high quality data to optimise completion design and hydraulic fracturing, calibrate reservoir models and inform future well design. CO₂ efficiency estimates and technology applications in unconventional fields including Vertical Seismic Profiling (VSP), cement cure analysis and hydraulic fracture optimisation are outlined. The upper end of one or two bare fibre optic cables are fixed inside a light-weight pressure control cap, while the downhole ends are deployed along the wellbore as they unspool from a disposable probe which is pumped along horizontal sections. Distributed Acoustic Sensing (DAS) is used for seismic and micro-seismic fracture analysis, whereas Distributed Temperature Sensing (DTS) is used to monitor well and near wellbore fluids. The high-quality data is used both in real time and subsequent enhanced analysis with disposable fibre having been successfully deployed in over 200 unconventional wells. The high level of acoustic and strain coupling as well as the elevated sensitivity of disposable bare optic fibre produce high quality data, with recent studies favourably comparing disposable fibre data with that obtained by retrievable fibre optic intervention. When compared with well monitoring methods utilising Wireline or Coiled Tubing, the disposable fibre system is extremely light weight with a micro footprint, requires only one person to deploy, has static seals, and does not require a BOP. The result is a low risk, efficient, method of highly sensitive, complete wellbore, fibre optic sensing. The transportation weight saving, reduced survey time, power consumption and reduced personnel requirements result in significant operational CO₂ reductions. Examples of unconventional well VSP, cement cure analysis, well integrity and fracture optimisation applications demonstrate efficiency gains and impact on asset economics. Unconventional field lifecycle applications of a new disposable fibre optic system are presented along with field optimisation and economic benefits. In addition, an example operation illustrating comparative CO₂ emissions for a hydraulic fracture monitoring application demonstrates disposable fibre CO₂ emissions at 8% of comparable wireline operations.
- Oceania > Australia (0.94)
- North America > United States > Texas (0.29)
- Europe > United Kingdom > Scotland (0.28)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (13 more...)
A Novel Shale Well Production Forecast Model Achieves >95% Accuracy Using Only 1.5 Years of Production Data
Haider, Syed (King Abdullah University of Science and Technology, Sinopec Tech Middle East R&D Center, Saudi Arabia) | Saputra, Wardana (University of Texas, Austin, USA) | Patzek, Tadeusz W. (King Abdullah University of Science and Technology, Saudi Arabia)
Abstract Objective Reliable production forecasting for shale wells is crucial for investment decisions, optimized drilling rate, energy security policies, and informed green transition scenarios. The industry has struggled with inaccurate production estimates from decline curve analysis (DCA) and from a long production history requirement for data-driven models. We have developed a state-of-the-art, physics-guided, data-driven model for accurate production forecast of unconventional wells for up to 10 years into the future. With an error of less than 5%, our hybrid model requires only 1.5 years of production data. The method facilitates long-term production diagnostics, well survival probability estimates, and profitable economic decisions. Method The hybrid state-of-the-art production forecast method combines our τ-M physical scaling model with the higher-order derivatives of the production rate. For a set of 4000 wells, the first 1.5 years of production data were used to develop a universal hybrid model to estimate the pressure interference time, τ, for each well. The estimated τ is used to calculate the stimulated mass, M, of individual wells using the physical scaling curve. Finally, the data-driven estimate of τ, and physics-driven estimates of M are used to forecast future well production and well survival probability with time. Results The robustness of the hybrid model has been tested on 6000 new wells in the Barnett, Haynesville, Eagle Ford, and Marcellus shale plays. Using the initial 1.5 years of production data and a single hybrid model, the predicted pressure interference time, τ, for 6000 wells has an R of 0.98. The maximum error in the predicted cumulative production of 2000 Barnett wells for any given year between the 2 year of production to the 15 year of production is only 2%. Similarly, the maximum error in the predicted cumulative production for Marcellus (500 wells), Haynesville, (1500 wells) and Eagle Ford (200 wells), is 2%, 5%, and 3%, respectively. The achieved outstanding accuracy is further used to calculate the well survival probability with time and optimize the future drilling rate required to sustain a given energy demand. Novelty We have developed a new, robust state-of-the-art hybrid model for unconventional well production forecasting. The model achieves an outstanding accuracy of > 95% and uses only the initial 1.5 years of production data. Early and accurate estimation of future production governs future investment decisions, re-fracking strategy, and improved energy security strategy.
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (0.67)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.67)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.50)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (44 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Production forecasting (1.00)
- (3 more...)
Dynamic Fracture Characterization Using Multiphase Rate Transient Analysis of Flowback and Production Data
Zhang, Zhengxin (China University of Petroleum Beijing) | Sun, Guoqing (Northeast Petroleum University) | Zhou, Xingze (PetroChina Changqing Oilfield Company) | Dang, Kaiyan (Shaanxi YanChang Petroleum Group Co., Ltd.) | Su, Xing (Pennsylvania State University)
Abstract This study presented a comprehensive method for characterizing reservoir properties and hydraulic fracture (HF) closure dynamics using the Rate Transient Analysis (RTA) of flowback and production data. The proposed method includes straight-line analysis (SLA), type-curve analysis (TCA), and model history matching (MHM), which are developed for scenarios of two-phase flow in fracture, stimulated reservoir volume (SRV), and NSRV domains. HF closure dynamics are characterized by two key parameters: pressure-dependent permeability and porosity controlled by fracture permeability-modulus and compressibility. The above techniques are combined into a generalized workflow to iteratively estimate the five parameters (four optional parameters and one fixed parameter) by reconciling data in different domains of time (single-phase water flow, two-phase flow, and hydrocarbon-dominated flow), analysis methods (SLA, TCA, MHM), and phases (water and hydrocarbon phase). We used flowback and production data from a shale gas well in the US to verify the practicability of the method. The analysis results of the field cases confirm the good performance of the newly developed comprehensive method and verify the accuracy in estimating the static fracture properties (initial fracture pore volume and permeability) and the HF dynamic parameters using the proposed generalized workflow. The accurate prediction of the decreasing fracture permeability and porosity, fracture permeability-modulus, and compressibility demonstrates the applicability of the workflow in quantifying HF dynamics. The field application results suggest a reduction of the fracture pore volume by 30%, and a reduction of the fracture permeability by 98% for shale gas well. Instead of a single analysis method for RTA, this paper proposed a comprehensive analysis method that includes SLA, TCA, and MHM. The interpretation results of the three analysis methods are mutually constrained, which can reduce the non-uniqueness problem of inversion. Compared with the others fracture characterization workflow that need fixed input and output parameters. This proposes general workflow not only completely characterizes the fracture closure dynamics but also can select the unknown parameters (to be determined) according to the actual scenarios of a well and the demands of reservoir engineers.
- Asia (1.00)
- North America > United States (0.89)
- North America > Canada > Alberta (0.28)
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
- Geology > Geological Subdiscipline > Geomechanics (0.70)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.56)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (8 more...)
Unique Production Conditions of Unconventional Wells in the Appalachian Basin; A Multi-Dimensional Assessment on Recovery
Rozploch, T. (Ayers Petroleum Consulting LLC, Canonsburg, PA, USA) | Ayers, K. (Ayers Petroleum Consulting LLC, Canonsburg, PA, USA) | Jacot, H. (H-Frac Consulting Services LLC, Wickenburg, AZ, USA) | Eshbaugh, K. (LOLA Energy PetroCo, LLC, Canonsburg, PA, USA)
Abstract This paper delves into the effects of long-term shut-in periods and production cycling on unconventional wet gas wells in the Appalachian Basin, where unique operational circumstances led to a long-term shut-in period. The unconventional Marcellus and Burkett wells were of a variety of production age. Ranging from depleted and operating under artificial lift, while others were recently flowed back and still in wellbore cleanup. A "long-term shut-in" refers to a shut-in period that occurs after a well has been in production for a substantial time period, rather than an intentional delay of production post-stimulation, known as "seasoning." The term "production cycling" refers to turning wells online to production for short periods of time and then shut-in for short periods of time. This was due to pipeline constraints, lease agreements, and/or transient operational conditions. The paper discusses the results of a comprehensive analysis, which included decline curve analysis, statistical analysis, hydraulic fracture modeling, build-up analysis, and rate transient analysis. The study considered many factors, such as inter-well spacing, stimulation, generational effects, wellbore boundaries, and reservoir/geologic characteristics. Overall, the study revealed a wide range of both positive and negative effects from both a reservoir and a production perspective, suggesting that factors such as well age, generation, spacing, and stimulation size were drivers. Near-term improvements were observed in previously damaged parent wells following the shut-in period. Several of the wells experienced a second, higher initial production rate than during flow back due to fluid cleanup effects. However, certain tightly spaced wells experienced negative effects on production in the longer term. In conclusion, this paper provides a comprehensive analysis of the effects of long-term shut-in periods and production cycling on unconventional wet gas wells in the Appalachian Basin. In real-time operations, many unique challenges are presented, gaining a deeper understanding of the downhole reservoir and long-term production effects will aid in more informed operational decisions in the future. The research outcomes emphasize the need for a more nuanced approach to unconventional reservoir development, and a careful consideration of the specific circumstances of each well. This study contributes to the ongoing efforts to improve the recovery of unconventional resources as these assets mature.
- North America > United States > West Virginia (1.00)
- North America > United States > Virginia (1.00)
- North America > United States > Pennsylvania (1.00)
Summary The loss of well integrity in oil and gas and CO2 injection wells provokes leaks that potentially pollute underground water reservoirs and the surrounding environment. The present publication reviews the existing literature investigating the loss of well integrity due to damage development in the cement sheath, focusing on qualitative and mainly quantitative information regarding cracks, effective permeability, and leak flows. Methods applied for leak detection on-site are reviewed, and the difficulties of these methods in providing quantitative results are highlighted. The outputs of laboratory experiments and computer simulations, considered essential to complement on-site measurements, are also reported. The review of the existing literature shows that for most of the damaged cement sheaths the observed crack widths range between 1 and 500 µm, the permeability ranges from 10 to 10 m, and the leak rates range between 10 and 10 000 mL/min for gas leaks and between 1 and 1000 mL/min for oil leaks.
- South America (1.00)
- North America > United States > Texas (1.00)
- Asia > Middle East (1.00)
- (3 more...)
- Research Report > New Finding (0.67)
- Overview (0.67)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (11 more...)
A Comprehensive Review of Fracture-Driven Interaction in Unconventional Oil and Gas Plays: Characterization, Real-Time Diagnosis, and Impact on Production
Singh, Harpreet (CNPC USA, Houston) | Cheng, Peng (CNPC USA, Houston) | Pan, Yuwei (CNPC, Beijing) | Li, Chengxi (CNPC USA, Houston) | Liu, Yu (CNPC, Beijing) | Wu, Xi (CNPC, Beijing) | Van Domelen, Mary (Well Data Labs) | Rogers, Samuel (RevSolz Corp.) | Taleghani, Arash Dahi (Pennsylvania State University) | Cao, Meng (The University of Texas at Austin)
Abstract The objective of this paper is to provide a comprehensive review of fracture-driven interaction (FDI) in unconventional oil and gas plays. This review aims to characterize FDI, diagnose it in real-time, and predict its impact on production. Methods, Procedures, Process The methodology of this study involves conducting a comprehensive literature review by collecting and analyzing data from various sources, including published literature, technical reports, and field data. The paper focuses on the characterization of FDI in terms of its controlling factors, types of FDI, and FDIs measured in different plays. Real-time diagnosis of FDI is explored using pressure timeseries analysis (PTA) and strain data analysis (SDA). Additionally, methods for predicting the impact of FDI on production were reviewed. Results, Observations, Conclusions Factors influencing FDI are reviewed, such as parent/off-set well depletion, petrophysical and geomechanical properties, well spacing, completion/stimulation parameters, and compressibility of fluid. The study outlines the characteristics of three FDI types (undrained poroelastic, indirect frac-hit, and direct frac-hit), and provides statistics of FDI pressures in various plays utilizing legacy monitoring and sealed wellbores. The study reviews real-time diagnosis and characterization of FDI and proposes three low-hanging fruit approaches for its improvement. Workflows for quantifying the impact of FDI on hydrocarbon production are not as effective as those for its diagnosis. Further research is needed to understand the impact of geological features, develop advanced diagnostic techniques, and quantitative methods to predict FDI's impact on production. Novel/Additive Information The study's findings and recommendations can inform the development of advanced real-time techniques to diagnose and characterize FDIs, improving fracturing designs. Gaps in knowledge are identified for further research.
- North America > United States > Texas (1.00)
- Asia > China (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.69)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.67)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- (54 more...)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- (10 more...)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Communications > Networks > Sensor Networks (0.45)
ABSTRACT High-cost deepwater, HP/HT, and extended-reach wells in conventional reservoirs drove impressive developments in LWD technology in recent decades. However, the length, cost, and mechanical specifications of traditional LWD tools make them generally unattractive for use in onshore unconventional reservoirs which present very different economic and technical challenges. This has led to the development of a compact integrated LWD tool optimized for geosteering, evaluating, and optimally completing unconventional reservoirs. Azimuthal spectral gamma ray, high-resolution ultrasonic imaging, and azimuthal sonic sensors are incorporated into a single 14.5 ft. (4.4 m) sensor collar. Applications of the azimuthal spectral gamma ray sensor include real-time geosteering, organic content evaluation, and clay content determination in uranium-bearing shales and carbonates. The ultrasonic imager provides high-resolution borehole images in both water-based and oil-based muds for fracture and fault detection, stress orientation, formation dip, and borehole stability applications. The ultrasonic imager also provides high-resolution caliper data. Azimuthally oriented compressional and shear slowness measurements from the azimuthal unipole sonic sensor provide important geomechanical, geophysical, and petrophysical information, including Poisson's ratio, porosity, and VTI shear anisotropy in horizontal wells. Log examples from various North American basins demonstrate the applications of this integrated LWD logging suite. Spectral gamma ray data from the Marcellus Shale differentiates high clay formations from cleaner, organic-rich, uranium-bearing formations, facilitating the evaluation of both organic content and clay content from K, U, Th data. Ultrasonic imager data from the Marcellus Shale and Permian Basin reveals natural fractures and formation dip, as well as borehole breakout in both normal and thrust fault stress regimes. Azimuthally focused unipole array sonic measurements from a horizontal well in the Wolfcamp formation resolves intrinsic VTI anisotropy. Together, these measurements allow operators to locate and geosteer in unconventional strata with higher organic content and/or geomechanical properties which are more conducive to hydraulic fracturing. These measurements also facilitate engineered completions, where frac stages are selectively placed to group together rocks with similar mechanical properties in each individual stage. Incorporating multiple logging sensors with particular value for unconventional reservoirs into a single compact drill collar represents a new direction in Logging While Drilling technology. In addition to the primary drilling and evaluation applications, recent log data have also revealed several novel uses, including: (1) observing early-time progression of borehole breakout by comparing ultrasonic images acquired while drilling and shortly after drilling, (2) detecting gas influx while drilling from decreases in ultrasonic imager amplitude, and (3) monitoring significant variations in mud slowness during various drilling operations using the ultrasonic mud cell. This integrated logging suite has also found applications beyond unconventional reservoirs, including use in fractured granite geothermal drilling, and, when combined with LWD resistivity, in conventional offshore wells.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.78)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (0.55)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- (35 more...)
Abstract The development of shale plays requires accurate forecasting of production rates and expected ultimate recoveries, which is challenging due to the complexities associated with production from hydraulically fractured horizontal wells in unconventional reservoirs. Traditional empirical models like Arps decline are inadequate in capturing these complexities, and long-term forecasting is hindered by the challenges posed by 3 phase flow. In response, a new physics-augmented, data-driven forecasting method has been proposed that efficiently captures these complexities. The proposed PI-based forecasting (PIBF) method combines data-driven techniques with the physics of propagation of dynamic drainage volume under transient flow conditions observed by unconventional wells for a prolonged period. The model requires only routinely measured inputs such as production rates and wellhead pressure, and efficiently captures the trend shift in gas-to-oil ratio caused by free gas liberation in the near-wellbore region. By using material balance and productivity index models, the proposed approach can forecast well performance and handle changing operational conditions during the well's lifecycle. Compared to existing empirical or analytical methods like Arps decline and RTA, the proposed method yields more accurate forecasting results, while still using easily available inputs. Empirical methods like Arps decline have low input requirements but lack physical insights, leading to inaccuracies and inability to handle changing operational conditions. Pure physics-based methods like RTA and reservoir simulation require more input properties that are often difficult to obtain, resulting in a low range of applicability. Overall, the proposed method offers a promising alternative to existing methods, effectively combining data-driven techniques with physics-based insights to accurately forecast well performance and handle changing operational conditions in unconventional reservoirs.
- Europe (0.68)
- Africa (0.68)
- North America > United States > Texas (0.48)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.48)
- Geology > Rock Type (0.30)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Production forecasting (1.00)
- (4 more...)