Time-tracking tests and interpretation for a horizontal well at different wellbore positions

2018 ◽  
Vol 6 (3) ◽  
pp. T699-T712 ◽  
Author(s):  
Ren-Shi Nie ◽  
Jin-Jing Ou ◽  
Su-Ran Wang ◽  
Qi Deng ◽  
Ming Qin ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Horizontal Wells ◽  
Test Method ◽  
Curve Shape ◽  
Pressure Data ◽  
Small Water ◽  
Horizontal Wellbore ◽  
Large Water ◽  
Water Cut ◽  
Production Conditions

We have developed a time-tracking test method for pressure buildup tests of horizontal wells to reduce the costs associated with testing wells. The time-tracking test method requires several tests that are performed chronologically from the midsection of the horizontal wellbore to the kickoff point. The purpose of time-tracking tests is to determine the production conditions of horizontal wells that allow the tests to be conducted at the kickoff point. Two horizontal wells associated within a sandstone oil reservoir were specifically chosen to determine how our time-tracking test method is to be implemented. The two wells had completely different production conditions. One had a small gas rate and a large water cut, whereas the other had a large gas rate and a small water cut. We recorded and analyzed the tested pressure data at numerous wellbore positions along the same horizontal well. Then, we interpreted the tested pressure data and compared the test results at different points along each well using the test curve shape and the interpretation parameter values. Through comparisons of the two wells, we found that the well-test curve shape and the interpretation results of tests performed above the kickoff point were completely different from those of the tests at the midsection of the horizontal wellbore under the conditions of a large gas rate and a small water cut. If a horizontal well has a small gas rate and a large water cut, the well can be tested at the kickoff point in the well using the wireline. We recommend that field petroleum engineers adopt the time-tracking test method to judge whether their horizontal wells should be tested at the kickoff point.

scholarly journals Water Breakthrough Shape Description of Horizontal Wells in Bottom-Water Reservoir

2014 ◽  
Vol 2014 ◽  
pp. 1-9
Author(s):  
Shijun Huang ◽  
Baoquan Zeng ◽  
Fenglan Zhao ◽  
Linsong Cheng ◽  
Baojian Du
Keyword(s):  
Physical Model ◽  
Horizontal Well ◽  
Bottom Water ◽  
Water Reservoir ◽  
Horizontal Wells ◽  
Analysis Model ◽  
Heterogeneous Reservoir ◽  
Water Breakthrough ◽  
Original Oil In Place ◽  
Water Cut

Horizontal wells have been applied in bottom-water reservoir since their advantages were found on distribution of linear dropdown near wellbore, higher critical production, and more OOIP (original oil in place) controlled. In the paper, one 3D visible physical model of horizontal physical model is designed and built to simulate the water cresting process during the horizontal well producing and find water breakthrough point in homogenous and heterogeneous reservoir with bottom water. Water cresting shape and water cut of horizontal well in between homogenous and heterogeneous reservoir are compared on the base of experiment’s result. The water cresting pattern of horizontal well in homogeneous reservoir can be summarized as “central breakthrough, lateral expansion, thorough flooding, and then flank uplifting.” Furthermore, a simple analysis model of horizontal well in bottom water reservoir is established and water breakthrough point is analyzed. It can be drawn from the analysis result that whether or not to consider the top and bottom border, breakthrough would be located in the middle of horizontal segment with equal flow velocity distribution.

Design of Horizontal Wellbore in Dadas Shales of Turkey by Considering Wellbore Stability and Reservoir Geomechanics

2021 ◽  
Author(s):  
Sukru Merey ◽  
Can Polat ◽  
Tuna Eren
Keyword(s):  
Hydraulic Fracturing ◽  
Horizontal Well ◽  
Oil And Gas ◽  
Horizontal Wells ◽  
Horizontal Stress ◽  
Wellbore Stability ◽  
Horizontal Drilling ◽  
Horizontal Wellbore ◽  
Reservoir Geomechanics ◽  
Maximum Horizontal Stress

Abstract Currently, many horizontal wells are being drilled in Dadas shales of Turkey. Dadas shales have both oil (mostly) and gas potentials. Thus, hydraulic fracturing operations are being held to mobilize hydrocarbons. Up to 1000 m length horizontal wells are drilled for this purpose. However, there is not any study analyzing wellbore stability and reservoir geomechanics in the conditions of Dadas shales. In this study, the directions of horizontal wells, wellbore stability and reservoir geomechanics of Dadas shales were designed by using well log data. In this study, the python code developed by using Kirsch equations was developed. With this python code, it is possible to estimate unconfined compressive strength in along wellbore at different deviations. By analyzing caliper log, density and porosity logs of Dadas shales, vertical stress of Dadas shales was estimated and stress polygon for these shale was prepared in this study. Then, optimum direction of horizontal well was suggested to avoid any wellbore stability problems. According to the results of this study, high stresses are seen in horizontal directions. In this study, it was found that the maximum horizontal stress in almost the direction of North-South. The results of this study revealed that direction of maximum horizontal stress and horizontal well direction fluid affect the wellbore stability significantly. Thus, in this study, better horizontal well design was made for Dadas shales. Currently, Dadas shales are popular in Turkey because of its oil and gas potential so horizontal drilling and hydraulic fracturing operations are being held. However, in literature, there is no study about horizontal wellbore designs for Dadas shales. This study will be novel and provide information about the horizontal drilling design of Dadas shales.

Predicting Productivity Index of Horizontal Wells

2006 ◽  
Vol 129 (2) ◽  
pp. 89-95 ◽  
Author(s):  
Shaojun Wang ◽  
Joe Eaton
Keyword(s):  
Flow Resistance ◽  
Horizontal Well ◽  
Extreme Case ◽  
Horizontal Wells ◽  
Productivity Index ◽  
Horizontal Flow ◽  
Vertical Flow ◽  
Vertical Permeability ◽  
Horizontal Wellbore ◽  
New Equation

The popular Joshi model slightly overestimated the flow resistance of a horizontal well. As a result of this, the Joshi model underpredicts the productivity index (PI) of a horizontal well by a few percent. In the extreme case in which vertical permeability goes to zero, the Joshi model predicts a 0.0 stb∕day-psi PI, which is wrong. In this paper, the flow for a horizontal well is divided into three flows: the flow in the reservoir above the horizontal wellbore, the flow in the reservoir with a thickness of 2rw containing the horizontal wellbore, and a flow in the reservoir below the horizontal well bore. The second flow is assumed to be pure horizontal flow. The first and third flows can be further divided into a horizontal flow and a vertical flow. In this paper, the equation for each flow is provided, and then combining these flows we give the equation to calculate the effective PI of horizontal wells. In addition, when the horizontal wellbore is not located at the h∕2 midpoint of a reservoir, the Joshi model predicts an increasing PI, which is intuitively and mathematically an incorrect trend. This paper derives a new equation to compute the PI of horizontal wells when the wellbore is eccentric relative to the reservoir midpoint. The new equation generates the correct trend.

scholarly journals Experimental Analysis of Gas Holdup Measured by Gas Array Tool in Gas–Water Two Phase of Horizontal Well

Coatings ◽  
2021 ◽  
Vol 11 (3) ◽  
pp. 343
Author(s):  
Shuaifei Cui ◽  
Junfeng Liu ◽  
Xulong Chen ◽  
Qinze Li
Keyword(s):  
Horizontal Well ◽  
Simulation Experiment ◽  
Horizontal Wells ◽  
Gas Holdup ◽  
Interpolation Algorithm ◽  
Two Phase ◽  
Optical Fiber Probe ◽  
Gas Identification ◽  
Water Cut ◽  
First Time

In the gas-water two phase of horizontal well, gas holdup is usually obtained by inverse calculation of the water holdup measured by the array capacitance probes. Gas Array Tool (GAT) has been developed to directly measure gas holdup. This instrument has been introduced into China and its simulation experiment in gas-water two phase flow in horizontal wells has been carried out for the first time to study the applicability of gas holdup measurement. Firstly, the response principle and measurement method of GAT are analyzed; secondly, the experimental data of GAT under different flowrates, water cut, and different cable speed are plotted and analyzed; finally, the gas holdup data measured by GAT and Capacitance Array Tool (CAT) are compared by using an interpolation algorithm. It is found that the response of the optical fiber probe is consistent and stable. It also proves the accuracy of gas identification and the applicability of gas holdup measurement under test conditions by GAT, which lays a foundation for further gas holdup measurement, interpretation, and field test in the future.

scholarly journals Study of the horizontal sidetracking efficiency using hydrodynamic modeling (on the example of a Kazakhstani field)

2022 ◽  
Vol 320 (1) ◽  
pp. 42-50
Author(s):  
K.A. Soltanbekova ◽  
◽  
B.K. Assilbekov ◽  
A.B. Zolotukhin ◽  
◽  
...  
Keyword(s):  
Horizontal Well ◽  
Horizontal Wells ◽  
Vertical Wells ◽  
Optimal Length ◽  
Pressure Losses ◽  
Rate Versus ◽  
Horizontal Wellbore ◽  
Effective Development ◽  
Complex Architecture ◽  
Economic Criteria

One of the modern approaches for the effective development of small deposits is the construction and operation of wells with a complex architecture: horizontal wells (HW), sidetracks (BS, BGS), multilateral wells (MLW). Sidetracking makes it possible to reanimate an old well that is in an emergency state or inactivity for technological reasons, by opening layers that have not been previously developed, bypassing contamination zones, or watering the formation. This study examines the possibility of using horizontal sidetracks in the operating wells of the field of the Zhetybai group. To select the optimal length of the horizontal sidetrack of the wells, graphs of the dependences of the change in flow rate versus length of the horizontal well were built, taking into account the pressure losses due to friction. It can be seen from the dependence of NPV versus length of the horizontal wellbore that the maximum NPV is achieved with a horizontal wellbore length of 100 m. A further increase in the length of the horizontal wellbore leads to a decrease in NPV. This is due, firstly, to a decrease in oil prices, and secondly, interference of wells, a small number of residual reserves, and a small oil-bearing area. As a result of a comparison of technical and economic criteria, the optimal length of a horizontal wellbore is from 100-300 meters. Comparison of the flow rates of vertical wells and wells with horizontal sidetracks showed a clear advantage over the latter in all respects.

SUCCESSFUL APPLICATION AND LIMITATIONS OF HORIZONTAL WELLS

2021 ◽  
Vol 5 (12(81)) ◽  
pp. 4-8
Author(s):  
S. Abbasova
Keyword(s):  
Oil Recovery ◽  
Horizontal Well ◽  
Horizontal Wells ◽  
Field Application ◽  
Vertical Wells ◽  
Flow Rates ◽  
Reservoir Conditions ◽  
Horizontal Wellbore ◽  
The Impact ◽  
Working Agent

In fields with low-permeable reservoirs, the use of vertical wells becomes economically unprofitable, since a significant amount of reserves remains not involved in development. In these conditions, the most rational use of horizontal wells becomes. A horizontal well is drilled parallel to the plane of the reservoir and can drain a larger area than a vertical one, which makes it possible to increase the impact of the working agent. This, in turn, leads to an increase in well productivity and, ultimately, to an increase in oil recovery of productive formations. Due to the horizontal wellbore, fractured areas are exposed, due to which the flow rates of these wells increase somewhat compared to vertical ones. It becomes possible to develop a reservoir with minimal drawdowns with a much smaller number of wells. The purpose of this article is to provide a brief overview of the field application of horizontal wells in various reservoir conditions. The review of economically successful and unsuccessful wells allows the creation of a certain kind of list of parameters that are of the greatest importance for consideration in order to select a commercially successful application of horizontal wells.

Water-and-Gas Shutoff Technologies in Horizontal Wells on North Komsomolskoe Field: Screening and Successful Trial

2021 ◽  
Author(s):  
Timur Eduardovich Nigmatullin ◽  
Vladislav Yurievich Nikulin ◽  
Airat Rafaelevich Shaymardanov ◽  
Rinat Rifkhatovich Mukminov ◽  
Alexandr Yurievich Ivanov ◽  
...  
Keyword(s):  
Field Tests ◽  
Horizontal Wells ◽  
Combined Effect ◽  
Well Completion ◽  
The North ◽  
Geological Conditions ◽  
The World ◽  
Horizontal Wellbore ◽  
Control Devices ◽  
Water Cut

Abstract The article describes the choosing a water-and-gas shutoff technology in horizontal wells (HW) drilled in terrigenous reservoirs of the North Komsomolskoye field. The well completion system is characterized by the use of liners equipped with external liner packers and inflow control devices (ICD). To solve the problem, the world experience in the use the water-and-gas shutoff technologies in HW was studied. A matrix for choosing a technology with the use of technical means and combined effect was developed based on the type of isolated fluid, the type of reservoir and the method of well completion. The technology of installing a straddle system with cup packers and a blind inter-packer pipe in a horizontal wellbore was selected to increase the success of work on isolating the inflow of water and gas in difficult geological conditions of the North Komsomolskoye field. The technology was successfully tested: a producing well with almost 100% water cut was return to effective production. A similar straddle system, but with a perforated spacer pipe, was used for directional injection of sealants selected for the conditions of the North Komsomolskoye field into the water cut zone of the horizontal wellbore. The results of pilot field tests indicate that there is a prospect of using water-and-gas shutoff technologies to limit water and gas inflow at the North Komsomolskoye field.

Modeling Proppant Transport Through Perforations in a Horizontal Wellbore

SPE Journal ◽  
2019 ◽  
Vol 24 (04) ◽  
pp. 1777-1789 ◽  
Author(s):  
Chu-Hsiang Wu ◽  
Mukul M. Sharma
Keyword(s):  
Horizontal Well ◽  
Suspended Solids ◽  
Numerical Technique ◽  
Horizontal Wells ◽  
Flow Conditions ◽  
Transport Efficiency ◽  
Proppant Transport ◽  
Slurry Flows ◽  
Horizontal Wellbore ◽  
Fluid Rheology

Summary Proppant placement plays a crucial role in ensuring that the conductivity of fractures is maintained after a hydraulic-fracturing treatment. The process involves the transport of suspended solids in a liquid, usually a water-based fluid, from the wellbore through perforations and finally into fractures. Many studies have focused on proppant settling and transport in fractures, but relatively few studies have investigated the proppant transport process in a wellbore through perforations. This paper addresses the important issue of proppant transport through perforations using a novel numerical technique. The objective is to evaluate the efficiency of proppant transport in a perforated horizontal well under different suspension flow conditions. In this paper, proppant transport through a perforated horizontal casing is modeled using a coupling of computational fluid dynamics and the discrete element method (CFD-DEM). Reasonable agreements are found between the modeling results and published experimental data. Furthermore, the effectiveness of proppant transport through a perforation is evaluated by the particle transport efficiency (Ei), which is defined as the mass fraction of particles transported through a perforation relative to the total mass of particles in the wellbore upstream of the perforation. The effects of casing diameter, proppant size, proppant density, proppant concentration, fluid-flow rate, fluid rheology, perforation size, and perforation orientation on Ei are investigated. The simulation results show that proppant inertia strongly influences proppant transport into a perforation. The proportion of proppant that goes into a perforation is typically much different than the proportion of fluid that goes into the same perforation. This results in an increase in the proppant concentration in the slurry as the slurry flows from the heel to the toe side of a plug-and-perforate stage. Results and models presented in this paper provide directions to quantify and potentially control proppant distribution in perforation clusters in horizontal wells.

WELL TESTING HORIZONTALGAS-CONDENSATE WELLS

2017 ◽  
pp. 56-61
Author(s):  
M. L. Karnaukhov ◽  
O. N. Pavelyeva
Keyword(s):  
Comparative Analysis ◽  
Skin Effect ◽  
Horizontal Wells ◽  
Gas Condensate ◽  
Low Permeability ◽  
Well Testing ◽  
Flow Capacity ◽  
Formation Zone ◽  
Horizontal Wellbore

The well testing of gas-condensate horizontal wells are discussed in the article and the comparative analysis of borehole flow capacity, depending on the mode of it’s operation is presented. Extra attention is focused on the issue of timely identification of the reasons for the reduction of fluid withdrawal from the reservoir. The presence of high skin effect is proved, which confirms the existence of low-permeability of bottomhole formation zone related to condensation in the immediate area of the horizontal wellbore.

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