Case Studies of Horizontal Well Design and Production Forecast

The most advanced technique to evaluate different solutions proposed for a field development plan consists of building a numerical model to simulate the production performance of each alternative. Fields covering hundreds of square kilometres frequently require a large number of wells. There are studies and software concerning optimal planning of vertical wells for the development of a field. However, only few studies cover planning of a large number of horizontal wells seeking full population on a regular pattern. One of the criteria for horizontal well planning is selecting the well positions that have the best reservoir properties and certain standoffs from oil/water contact. The wells are then ranked according to their performances. Other criteria include the geometry and spacing of the wells. Placing hundreds of well individually according to these criteria is highly time consuming and can become impossible under time restraints. A method for planning a large number of horizontal wells in a regular pattern in a simulation model significantly reduces the time required for a reservoir production forecast using simulation software. The proposed method is implemented by a computer script and takes into account not only the aforementioned criteria, but also new well requirements concerning existing wells, development area boundaries, and reservoir geological structure features. Some of the conclusions drawn from a study on this method are (1) the new method saves a significant amount of working hours and avoids human errors, especially when many development scenarios need to be considered; (2) a large reservoir with hundreds of wells may have infinite possible solutions, and this approach has the aim of giving the most significant one; and (3) a horizontal well planning module would be a useful tool for commercial simulation software to ease engineers' tasks.

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A Field Study of Horizontal Well Design in Reducing Water Coning

10.2118/30016-ms ◽

1995 ◽

Author(s):

G. Wu ◽

K. Reynolds ◽

B. Markitell

Keyword(s):

Field Study ◽

Horizontal Well ◽

Well Design ◽

Water Coning

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Integrated Completion Sensitivities for Horizontal-Well Design in the Vaca Muerta

Journal of Petroleum Technology ◽

10.2118/0917-0076-jpt ◽

2017 ◽

Vol 69 (09) ◽

pp. 76-79

Author(s):

Chris Carpenter

Keyword(s):

Horizontal Well ◽

Well Design ◽

Vaca Muerta

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Application of Walk-away VSP technology in shale gas horizontal well design

10.1190/igc2018-323 ◽

2018 ◽

Author(s):

Wei Zhang ◽

Liting Liu ◽

Chunhua Chen ◽

Fei Liu ◽

Hong Mi

Keyword(s):

Shale Gas ◽

Horizontal Well ◽

Walk Away ◽

Well Design

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Gazprom Neft Approach to Horizontal Well Production Logging Improvement. Case Studies

10.3997/2214-4609.201901840 ◽

2019 ◽

Author(s):

M. Kremenetskiy ◽

A. Ipatov ◽

M. Kolesnikov ◽

A. Sharipov ◽

E. Pahomov

Keyword(s):

Case Studies ◽

Horizontal Well ◽

Well Production

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Planning and Well Design for First North Kuwait Najmah Limestone Jurassic Horizontal Well - Case History

10.2118/170559-ms ◽

2014 ◽

Author(s):

Ravindra Shaligram Patil ◽

Vijay Saradhi Veluri ◽

Waleed Jawad Al-Baghli

Keyword(s):

Case History ◽

Horizontal Well ◽

Well Design

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Vertical to Horizontal - Ultra Deep Azimuthal Resistivity Tool UDAR Service Helping to Maximize Production

10.4043/31195-ms ◽

2021 ◽

Author(s):

Ahmed Zarroug El Sedeq ◽

Neal Hughes ◽

Tore Oian ◽

Piotr Byrski ◽

Jean-Michel Denichou ◽

...

Keyword(s):

Real Time ◽

Horizontal Well ◽

Optimal Placement ◽

Temperature Management ◽

Trajectory Design ◽

Time Inversion ◽

Reservoir Properties ◽

Gas Field ◽

Well Design ◽

Azimuthal Resistivity

Abstract Dvalin field, discovered in 2010-2012. The location of this field is in the Norwegian Sea, as shown in (Figure 1). Dvalin field is an HPHT gas field in Middle Jurassic sandstone in the Garn and Ile Formations – the former being homogeneous with better reservoir properties, during the later heterogenous with low quality. (DVALIN, 2020) The well 6507/7-Z-2 H objective is to produce hydrocarbons from the Jurassic reservoir section of the Dvalin field safely and cost-effectively. The well was planned to be drilled near vertical in the reservoir section and TD'ed at a maximum depth corresponding to the Garn Formation base. After the productivity results from Z-3-H well came in at the low end of expectations, it was evaluated and decided to change the well profile of the Z-2-H well from vertical reservoir penetration to a horizontal profile; to have two penetrations with a minimum of 150m MD separation in the upper high permeable streak and then drop to penetrate lower high permeable streak. This decision was conducted only three days before starting the 17.5-inch section on the subject well. One Team culture was the key to achieving this significant change successfully. The decision to change the well-profile was conducted after a thorough engineering evaluation, including offset well analysis, which was very limited as the closest horizontal well was more than 40 km away. As the well was not planned as a horizontal well, departure between the surface location and Target Easting & Northing was minimal. Therefore, a high turn and deeper inclination build were required, which added some complexity to the well design. One of the additional primary risks related to this change of trajectory design is deploying a more complex BHA design in the reservoir section with a full suite of LWD technologies run in an HT environment. In the planning phase, special consideration was needed to accurately simulate the expected circulating temperature and have proper procedures in place for temperature management and control. Being the first horizontal well in the field, thus detailed planning was key for successful execution. Ultra-Deep Azimuthal Resistivity Tool (UDAR) Reservoir-Mapping capability was considered to help optimize the landing and navigate within the reservoir section. A feasibility study was conducted, and a 2-receiver Ultra Deep Azimuthal Resistivity Tool BHA configuration was selected and deployed. During the execution, the Ultra Deep Azimuthal Resistivity Tool real-time inversion mapped the reservoir geometry, revealing resistive layers within the Garn formation, thereby facilitating optimal placement of the well to achieve the set objectives. The well execution was largely considered flawless, with the real-time Ultra Deep Azimuthal Resistivity Tool data and corresponding interpretations facilitating decisions.

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