Paleostructural control of hydrocarbon production from the Cretaceous Niobrara in a part of the Denver-Julesburg Basin of Colorado and Wyoming

2017 ◽  
Vol 54 (1) ◽  
pp. 33-48
Author(s):  
Tom Spurr ◽  
Jeff Ware
Keyword(s):  
Horizontal Wells ◽  
Niobrara Formation ◽  
Vertical Wells ◽  
Hydrocarbon Production ◽  
Horizontal Drilling ◽  
Water Currents ◽  
The Past ◽  
Bottom Hole ◽  
Porosity And Permeability ◽  
Reservoir Porosity

Horizontal drilling and fracture stimulation of the Niobrara Formation chalks within the last decade have resulted in a widespread resource play in the Denver-Julesburg (DJ) Basin where over 50,000 vertical wells had already penetrated the Niobrara. The first fracture-stimulated horizontal Niobrara well in the DJ Basin was drilled in 2005. By the end of 2015, over 2000 horizontal wells had been drilled targeting the Niobrara and these new wells have made over 120 MMBO and nearly 500 BCF. Thickness changes correlate with the varying success of hydrocarbon production from the Niobrara in a part of the DJ Basin of Colorado. In the study area, the Niobrara comprises four chalks with interbedded marlstones; from top to bottom the A, B, and C chalks, and the Fort Hays Limestone. The Niobrara B chalk is the primary target for horizontal drilling; both the A and C chalk are secondary targets. The Niobrara Formation is self-sourcing and the hydrocarbons in the study area are not thought to have migrated. Within the study area, productivity in the Niobrara may be directly related to thermal maturity. Regionally thinner Niobrara trends are more likely to contain more productive wells than where thicker Niobrara is present. Thin intervals also coincide with higher resistivity values in the Niobrara B chalk and higher bottom hole temperatures. Temperatures were likely elevated in these locations in the past which led to increased organic maturity. Reservoir porosity and permeability may be enhanced along thin trends where shallow water currents winnowed sediments. Mapping the interplay of thickness, resistivity, and temperature of the Niobrara Formation can greatly improve the success rate of drilling in this play.

scholarly journals THE ANALYSIS OF METHODS OF RESERVOIR POROSITY-PERMEABILITY PROPERTIES STUDY IN HORIZONTAL WELLS TO ESTIMATE THE BOTTOM-HOLE TREATMENT RESULTS

2016 ◽  
pp. 72-77
Author(s):  
I. I. Mannanov ◽  
L. I. Garipova
Keyword(s):  
Horizontal Wells ◽  
Practical Application ◽  
Treatment Results ◽  
Reservoir Properties ◽  
Bottom Hole ◽  
Reservoir Porosity ◽  
Analysis Of Dynamics

Obtaining of the information about reservoir properties of formations is the basis of designing and the results analysis of production stimulation methods. Now two directions have been widely studied and applied, i.e. the hydrodynamic studies implementation using the method of the level recovery and the prolong analysis of dynamics of well producing characteristics. The paper discusses the practical application of both approaches for estimation of the need in treatment and the results of production intensification methods.

Plug and Abandonment Environment in British Columbia

2019 ◽  
Author(s):  
Majid Bizhani ◽  
Élizabeth Trudel ◽  
Ian Frigaard
Keyword(s):  
British Columbia ◽  
Fractured Reservoirs ◽  
Horizontal Wells ◽  
Gas Production ◽  
Vertical Wells ◽  
Gas Industry ◽  
Testing Procedures ◽  
The Past ◽  
Production Wells ◽  
Well Abandonment

Abstract British Columbia (BC) has a significant oil & gas industry, with approximately 25,000 wells drilled in the province since the early 1900s. In the past few decades, the industry has changed from a balanced oil & gas production to activities dominated by unconventional gas production which is recovered by hydraulic fracturing. Concurrently, since 2000 there has been a shift from isolated vertical wells to pad-drilled horizontal wells. The older well stock at end-of-life combines with horizontal production wells and fractured reservoirs, the consequence of which is a growing wave of abandonment in BC, building over the next decade. This paper reviews the existing data on BC wells, as it is relevant to well abandonment operations. This includes the well architectures, trajectories, depths, testing procedures, etc.

An Intelligent Completion and Artificial Lift Technology to Develop Large Carbonate Reservoirs: Novel Completion and Zonal Water Injection via Remote Control Methods to Develop Horizontal Wells

2021 ◽  
Author(s):  
Jin Fu ◽  
Xi Wang ◽  
Guobin Yang ◽  
Shunyuan Zhang ◽  
Chen Chen ◽  
...  
Keyword(s):  
Remote Control ◽  
Data Collection ◽  
Water Adsorption ◽  
Water Injection ◽  
Horizontal Wells ◽  
Carbonate Reservoirs ◽  
Control Methods ◽  
Vertical Wells ◽  
Horizontal Drilling ◽  
Artificial Lift

Abstract There are several large carbonate reservoirs that have drawn great attention of researchers in recent years. After optimization of drilling technologies, how to deploy artificial lift technologies to develop them more efficiently is another concern. Conventional zonal water injection technologies require repetitive operation with wirelines and cables, causing extensive tests and low efficiency. However, an intelligent zonal water injection string consisting of several preset cable packers, water injection pressure gauges, formation pressure gauges and downhole flow meters has simply optimized water injection parameters and efficiently developed all reservoirs in some China's mature oilfields, especially when the string is integrated with remote monitoring and control methodologies. With the rapid development of horizontal drilling and extended reach well drilling technologies, borehole conditions are becoming more and more complicated, which has brought more challenges to water adsorption testing of horizontal intervals and deployment of zonal water injection instruments. Compared with vertical wells, the water adsorption test and string running are more challenging for horizontal wells, in which we are faced by many a problem during zonal water injection, such as competitive slack off and tight pull, excessive or inadequate water injection, complicated operation process. Besides, well deviation, dog leg and horizontal section length shall be all taken into consideration during zonal water injection for horizontal wells. Therefore, novel strings and tools should be deployed. Now tight pull, slack off and long operation periods are common problems during zonal water injection of horizontal intervals. After dedicated research, a set of wireless intelligent water injection strings for horizontal wells has been invented. Based on pressure pulse water distribution technique, the water injection string is eligible for 32-stage adjustment, so one strip may accomplish testing, adjusting, injection, measurement and downhole data collection, in addition to automatic error correction during water injection. The field trial shows that this novel string may be tripped in and out smoothly, packers are set securely and released easily, in order to adjust opening of each water injection nozzle in the ground, with an error of no more than ±10%. Therefore, the novel completion and water zonal water injection string is capable of injecting water precisely via remote control methods. The wireless intelligent water injection string for horizontal wells that combines testing, adjusting, injection, measuring and data collection in one trip provides us with many downhole data, such as pressure, flow rate, temperature and so on. Therefore, water injection volume for each zone is monitored and controlled down hole. This technology is applicable for both horizontal and vertical wells that require zonal water injection.

scholarly journals Applying geological and mathematical modeling to predict fluid influx in horizontal wells (the case of Kalamkas oil field)

2021 ◽  
Vol 3 (3) ◽  
pp. 3-10
Author(s):  
B. H. Nugmanov
Keyword(s):  
Mathematical Modeling ◽  
Flow Rate ◽  
Oil Production ◽  
Horizontal Wells ◽  
Oil Field ◽  
Horizontal Drilling ◽  
Filtration Resistance ◽  
Bottom Hole ◽  
Modern Methods ◽  
Hydrodynamic Calculations

One of the ways to increase well oil production is to reduce the filtration resistance of the bottom-hole zone. Along with well-known stimulation methods, such as modern methods of treating wells bottom-hole zone, side tracking (drilling of lateral horizontal boreholes) is of great interest. The following works have been implemented Kalamkas field: a complex of geological, geophysical and field exploration; correlation schemes to track the lithology of the formation; clarifying structural maps and engineering maps; justifying activities to select one or more wells for horizontal drilling; hydrodynamic calculations and estimating their flow rate.

Domestic rotary steerable systems development potential for drilling horizontal wells

2020 ◽  
pp. 74-80
Author(s):  
V. V. Saltykov ◽  
Yu. S. Makovsky ◽  
M. M. Mansurova
Keyword(s):  
Horizontal Wells ◽  
Systems Development ◽  
Oil Field ◽  
High Tech ◽  
Technological Solution ◽  
Deviation Angle ◽  
Vertical Wells ◽  
Special Equipment ◽  
The Past

A complex of special equipment is required for the construction of high-tech wells. The basis of modern time efficient, precise and safe drilling is rotary steerable systems (RSS). For the past five years, rotary steerable systems have been using in Russia as a technical and technological solution to reduce accidents and to improve the quality of well construction with large vertical deviations of the extended drilling radius. These systems allow drilling to be oriented along the entire length of the well. Rotary steerable systems allows drilling both perfectly vertical wells with a deviation angle of not more than 0,2°, and horizontal wells more than 2 000 metres long. Implementation of rotary steerable systems allows building wells with extremely extended reach and conducting wells in 1–2 metres thick reservoirs with precision. In 2016, OktoGeo LLC carried out pilot well program with APS Technology's 172 mm RSS (with power section) at an oil field in the territory of KhantyMansiysk Autonomous Okrug — Ugra. All the rotary steerable system positioning programs were completed based on the results of that work and results of drilling 2 205 metres long directional well.

Improving Proppant Placement Success in Horizontal Wells in Layered Reservoirs in the Sultanate of Oman

2021 ◽  
Author(s):  
Andrew Boucher ◽  
Josef Shaoul ◽  
Inna Tkachuk ◽  
Mohammed Rashdi ◽  
Khalfan Bahri ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Complex Geometry ◽  
Horizontal Wells ◽  
Vertical Position ◽  
Sultanate Of Oman ◽  
Vertical Wells ◽  
Multiple Fractures ◽  
Initiation Point ◽  
Interval Selection ◽  
Geological Units

Abstract A gas condensate field in the Sultanate of Oman has been developed since 1999 with vertical wells, with multiple fractures targeting different geological units. There were always issues with premature screenouts, especially when 16/30 or 12/20 proppant were used. The problems placing proppant were mainly in the upper two units, which have the lowest permeability and the most heterogeneous lithology, with alternating sand and shaly layers between the thick competent heterolith layers. Since 2015, a horizontal well pilot has been under way to determine if horizontal wells could be used for infill drilling, focusing on the least depleted units at the top of the reservoir. The horizontal wells have been plagued with problems of high fracturing pressures, low injectivity and premature screenouts. This paper describes a comprehensive analysis performed to understand the reasons for these difficulties and to determine how to improve the perforation interval selection criteria and treatment approach to minimize these problems in future horizontal wells. The method for improving the success rate of propped fracturing was based on analyzing all treatments performed in the first seven horizontal wells, and categorizing their proppant placement behavior into one of three categories (easy, difficult, impossible) based on injectivity, net pressure trend, proppant pumped and screenout occurrence. The stages in all three categories were then compared with relevant parameters, until a relationship was found that could explain both the successful and unsuccessful treatments. Treatments from offset vertical wells performed in the same geological units were re-analyzed, and used to better understand the behavior seen in the horizontal wells. The first observation was that proppant placement challenges and associated fracturing behavior were also seen in vertical wells in the two uppermost units, although to a much lesser extent. A strong correlation was found in the horizontal well fractures between the problems and the location of the perforated interval vertically within this heterogeneous reservoir. In order to place proppant successfully, it was necessary to initiate the fracture in a clean sand layer with sufficient vertical distance (TVT) to the heterolith (barrier) layers above and below the initiation point. The thickness of the heterolith layers was also important. Without sufficient "room" to grow vertically from where it initiates, the fracture appears to generate complex geometry, including horizontal fracture components that result in high fracturing pressures, large tortuosity friction, limited height growth and even poroelastic stress increase. This study has resulted in a better understanding of mechanisms that can make hydraulic fracturing more difficult in a horizontal well than a vertical well in a laminated heterogeneous low permeability reservoir. The guidelines given on how to select perforated intervals based on vertical position in the reservoir, rather than their position along the horizontal well, is a different approach than what is commonly used for horizontal well perforation interval selection.

scholarly journals Mathematical description of a bounded oil reservoir with a horizontal well

2021 ◽  
Vol 2 (1) ◽  
pp. 67-76
Author(s):  
T. N. Nzomo ◽  
S. E Adewole ◽  
K. O Awuor ◽  
D. O. Oyoo
Keyword(s):  
Pressure Distribution ◽  
Effective Permeability ◽  
Horizontal Well ◽  
Horizontal Wells ◽  
Oil Reservoir ◽  
Vertical Wells ◽  
Anisotropic Permeability ◽  
Time Approximation ◽  
Reservoir Geometry ◽  
Short Time

Horizontal wells are more productive compared to vertical wells if their performance is optimized. For a completely bounded oil reservoir, immediately the well is put into production, the boundaries of the oil reservoir have no effect on the flow. The pressure distribution thus can be approximated with this into consideration. When the flow reaches either the vertical or the horizontal boundaries of the reservoir, the effect of the boundaries can be factored into the pressure distribution approximation. In this paper we consider the above cases and present a detailed mathematical model that can be used for short time approximation of the pressure distribution for a horizontal well with sealed boundaries. The models are developed using appropriate Green’s and source functions. In all the models developed the effect of the oil reservoir boundaries as well as the oil reservoir parameters determine the flow period experienced. In particular, the effective permeability relative to horizontal anisotropic permeability, the width and length of the reservoir influence the pressure response. The models developed can be used to approximate and analyze the pressure distribution for horizontal wells during a short time of production. The models presented show that the dimensionless pressure distribution is affected by the oil reservoir geometry and the respective directional permeabilities.

Application Of Tandem Rotary Steerable-Positive Displacement Motor Bottom Hole Assembly In Drilling Horizontal Wells: Case Study Of Three East Siberia Wells

2011 ◽  
Author(s):  
Zimuzor Michael Okafor ◽  
Andrew John Buchan ◽  
Dmitry Diyanov ◽  
Sheldon Andre Rawlins ◽  
Grigoriy Zhadan ◽  
...  
Keyword(s):  
Horizontal Wells ◽  
East Siberia ◽  
Positive Displacement ◽  
Bottom Hole ◽  
Bottom Hole Assembly

Geomechanical Approach in Classification of Borehole Failures in Fractured Carbonates of Boca De Jaruco Field

2021 ◽  
Author(s):  
Anna Vladimirovna Norkina ◽  
Iaroslav Olegovich Simakov ◽  
Yuriy Anatoljevich Petrakov ◽  
Alexey Evgenjevich Sobolev ◽  
Oleg Vladimirovich Petrashov ◽  
...  
Keyword(s):  
Stress State ◽  
Horizontal Wells ◽  
Horizontal Stress ◽  
In Situ Stress ◽  
Vertical Wells ◽  
Stress Regime ◽  
Geophysical Information ◽  
The Republic ◽  
Maximum Horizontal Stress

Abstract This article is a continuation of the work on geomechanically calculations for optimizing the drilling of horizontal wells into the productive reservoir M at the Boca de Haruco field of the Republic of Cuba, presented in the article SPE-196897. As part of the work, an assessment of the stress state and direction was carried out using geological and geophysical information, an analysis of the pressure behavior during steam injections, cross-dipole acoustics, as well as oriented caliper data in vertical wells. After the completion of the first part of the work, the first horizontal wells were successfully drilled into the M formation. According to the recommendations, additional studies were carried out: core sampling and recording of micro-imager logging in the deviated sections. Presence of wellbore failures at the inclined sections allowed to use the method of inverse in-situ stress modeling based on image logs interpretation. The classification of wellbore failures by micro-imager logging: natural origin and violations of technogenic genesis is carried out. The type of breakout is defined. The result of the work was the determination of the stress state and horizontal stresses direction. In addition, the article is supplemented with the calculation of the maximum horizontal stress through the stress regime identifier factor.

Evaluating the Performance of Horizontal Multi-Frac Wells in a Depleted Gas Condensate Reservoir in Sultanate of Oman

2022 ◽  
Author(s):  
Josef R. Shaoul ◽  
Jason Park ◽  
Andrew Boucher ◽  
Inna Tkachuk ◽  
Cornelis Veeken ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Horizontal Wells ◽  
Gas Condensate ◽  
Integrated Analysis ◽  
Single Fracture ◽  
Reservoir Pressure ◽  
Well Test ◽  
Vertical Wells ◽  
Fracture Conductivity ◽  
Half Length

Abstract The Saih Rawl gas condensate field has been producing for 20 years from multiple fractured vertical wells covering a very thick gross interval with varying reservoir permeability. After many years of production, the remaining reserves are mainly in the lowest permeability upper units. A pilot program using horizontal multi-frac wells was started in 2015, and five wells were drilled, stimulated and tested over a four-year period. The number of stages per horizontal well ranged from 6 to 14, but in all cases production was much less than expected based on the number of stages and the production from offset vertical wells producing from the same reservoir units with a single fracture. The scope of this paper is to describe the work that was performed to understand the reason for the lower than expected performance of the horizontal wells, how to improve the performance, and the implementation of those ideas in two additional horizontal wells completed in 2020. The study workflow was to perform an integrated analysis of fracturing, production and well test data, in order to history match all available data with a consistent reservoir description (permeability and fracture properties). Fracturing data included diagnostic injections (breakdown, step-rate test and minifrac) and main fracture treatments, where net pressure matching was performed. After closure analysis (ACA) was not possible in most cases due to low reservoir pressure and absence of downhole gauges. Post-fracture well test and production matching was performed using 3D reservoir simulation models including local grid refinement to capture fracture dimensions and conductivity. Based on simulation results, the effective propped fracture half-length seen in the post-frac production was extremely small, on the order of tens of meters, in some of the wells. In other wells, the effective fracture half-length was consistent with the created propped half-length, but the fracture conductivity was extremely small (finite conductivity fracture). The problems with the propped fractures appear to be related to a combination of poor proppant pack cleanup, low proppant concentration and small proppant diameter, compounded by low reservoir pressure which has a negative impact on proppant regained permeability after fracturing with crosslinked gel. Key conclusions from this study are that 1) using the same fracture design in a horizontal well with transverse fractures will not give the same result as in a vertical well in the same reservoir, 2) the effect of depletion on proppant pack cleanup in high temperature tight gas reservoirs appears to be very strong, requiring an adjustment in fracture design and proppant selection to achieve reasonable fracture conductivity, and 3) achieving sufficient effective propped length and height is key to economic production.

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