A Case Study: Field Development Plan for a Highly Overpressured Gas Reservoir in China by a Multidisciplinary Consulting Team

2002 ◽  
Author(s):  
Haiping Li ◽  
Hongjie Xiong ◽  
James Wang ◽  
Rolf J. Broetz ◽  
Hilary Azoba ◽  
...  
Keyword(s):  
Development Plan ◽  
Gas Reservoir ◽  
Field Development

An Approach and Case Study on Determination of the Sulfur Deposition Radius in High Sulfur Gas Reservoir

2014 ◽  
Vol 1073-1076 ◽  
pp. 592-596
Author(s):  
Pei Luo ◽  
Yu Ming Luo ◽  
Kai Ma ◽  
Biao Zhang ◽  
Sha Sha Song
Keyword(s):  
Sulfur Deposition ◽  
Mixed Gas ◽  
Gas Reservoir ◽  
Gas Field ◽  
Gas Well ◽  
Pressure Transient ◽  
Field Development ◽  
Eastern Sichuan Basin

In the process of high sulfur gas field development, the sulfur will separate out from the mixed gas when the pressure near wellbore area drops to a critical pressure of H2S. This will reduce the reservoir porosity greatly and decrease the gas well productivity as well. This paper discusses the characteristics of pressure transient testing plots when sulfur deposition occurs based on the redial composite reservoir model. And introduce an approach to determine the sulfur deposition radius near the wellbore with pressure transient testing interpretation in high sulfur gas reservoir. The method has been applied in some high sulfur gas field in eastern Sichuan Basin. The result shows that the method is simple and practical.

Barik Reservoir Description- An Evolving Concept

2015 ◽  
Author(s):  
Khalil Al Rashdi ◽  
David Spain
Keyword(s):  
Tight Gas ◽  
Gas Reservoir ◽  
Field Development ◽  
Central Processing ◽  
Current State ◽  
Tight Gas Reservoir ◽  
Reservoir Description ◽  
The Cost ◽  
Oil Company

Abstract Khazzan field, situated in Block 61 in northern Oman, contains hydrocarbons at several deep levels, including the Barik, Miqrat, Amin and Buah formations. The Barik and Amin reservoirs are being developed in the southern portion of the block to produce 1 bcf/d of gas by end 2017. The development, jointly owned by Oman Oil Company (40%) and BP (60% and operator), will cost over 16 billion US$ and will include a central processing facility and surface facilities for about 300 wells. Most of the wells will be 1000m long horizontal wells, completed using multiple hydraulic fracturing techniques. The two other reservoirs, Miqrat and Buah, contain high H2S levels; these will not be developed at this phase due to high subsurface uncertainties and the cost to process the sour development. This paper presents a case study of an evolving reservoir description of a large, tight gas reservoir, the Barik Formation. It is rare to embark on a major “greenfield” reservoir development of a tight gas reservoir with limited static and almost no dynamic data. The reservoir description is essential to the successful evaluation and management of the inherent subsurface uncertainty at this stage in the field development. Building an associated appraisal plan and being flexible to new understanding is required to make the development a success. The reservoir description is guiding the ongoing appraisal activities in an attempt to reduce the risk and increase the overall project value. This paper presents the evolution of the reservoir description over the last 6 years of BP activity in Block 61 in the Sultanate of Oman. It reviews three stages of reservoir description: Pre-Appraisal, Mid-Appraisal, and Development. The pre-appraisal description was built using the pre-bid data package and published literature to support the commercial access decisions. The Mid Appraisal description provided a health-check for development readiness and appraisal plan revision. Finally, the Development description is presented in a 3D geo-cellular model which is based on the summary of the appraisal activities and supporting field development learnings. The paper discusses these descriptions and the benefits of the changing description, explanation of the advantages of front end loading at the early appraisal stage and how this has led us to our current state

Dynamic Modeling Workflow for an Unconventional Biogenic Gas Reservoir with Multistage Hydraulic Fracture. A Case Study of Miocene Gachsaran Formation, Abu Dhabi, United Arab Emirates

2021 ◽  
Author(s):  
Abdelghani Gueddoud ◽  
Ahmed Al Hanaee ◽  
Riaz Khan ◽  
Atef Abdelaal ◽  
Redy Kurniawan ◽  
...  
Keyword(s):  
Hydraulic Fracture ◽  
Development Plan ◽  
Unconventional Reservoirs ◽  
Hydraulic Fractures ◽  
Flow Mechanism ◽  
Gas Reservoir ◽  
Full Field ◽  
Gas Concentration ◽  
Biogenic Gas ◽  
Field Development

Abstract The Miocene Gachsaran Formation across Onshore Abu Dhabi and Dubai possesses high potential of generating shallow biogenic gas. A dynamic model and field development plan generated based on a detail G&G analysis to understand and evaluate its capability as promising gas resources. Specific approaches and workflow generated for volumetric and dynamic reservoir model capable of defining the most viable development strategy of the field from both an economic and technical standpoint. The proposed workflow adapts also the development plan from single pad-scale to full field development plan. A fine-grid field-scale with more than hundreds of Pads covering the sweet spot area of three thousands of square kilometers including structure, reservoir properties built based on existing vertical wells, newly drilled horizontal wells and seismic interpretation. In this paper, a robust workflow for big and complex unconventional biogenic gas reservoir modeling and simulation technique have been developed with hydraulic fracture and stimulated area created through LGR. Independent workflows generated for the adsorbed gas in place calculation, desorption flow mechanism, and Pads field development plan. An accuracy on in place calculation, desorption flow mechanism and Pseudo steady state flow through direct and indirect total gas concentration measured using (1) Pressurize core and sorption isotherm capacity experiment, (2) Langmuir /BET function and Vmax scaling curves for each grid cells, and (3) Gas concentration versus TOC relationship. Field development plan for unconventional shallow biogenic gas reservoirs is possible only if a communication network created through hydraulic fractures connects a huge reservoir area to the wellbore effectively. A complete workflow presented for modeling and simulation of unconventional reservoirs, which in-corporates the characterization of hydraulic fracture and their interaction with reservoir matrix. Dual porosity model has been constructed with accurate in place calculation through scaling the Langmuir function and calculation Vmax for each grid cell of the full field model, The single Pad design approach in the development plan has exhibited great advantages in terms of improvement in the quality and flexibility of the model, reduction of working time with the same Pad model design which is adapted for the full field development plan. The proposed unconventional modeling and field development plan workflow provides an efficient and useful unconventional dynamic model construction and full field development planning under uncertainty analysis. Minimizing the uncertainty in place calculation and production forecasting for unconventional reservoirs necessitates an accurate direct and indirect data measurement of gas concentration and flow mechanism through the laboratory measurement. Field development plan for unconventional reservoirs is possible only if fracture network can be created through hydraulic fractures that connects a huge reservoir area to the wellbore effectively through pad completion.

Benefit of Data Integration (Biostratigraphic Data) in Field Development –B4 Gas Reservoir Case Study

2015 ◽  
Author(s):  
Andrew Ogbuli ◽  
Omagbemi Kakayor ◽  
Alia Bahry ◽  
Yaqub Adepoju ◽  
Chukwunweike Awa ◽  
...  
Keyword(s):  
Data Integration ◽  
Gas Reservoir ◽  
Field Development

A Real Case Study: Field Development Plan Evaluations for Oso Field

2015 ◽  
Author(s):  
F. Sierra ◽  
A. Monge ◽  
S. Leon ◽  
F. Vasquez ◽  
J. Garcia ◽  
...  
Keyword(s):  
Development Plan ◽  
Real Case ◽  
Field Development

Assessing Field Development Plan for Green Fields Using an Integrated Asset Approach, an Angolan Case Study

2015 ◽  
Author(s):  
Jose Alberto Rojas Mora ◽  
Siew Hiang Khor ◽  
David Mason ◽  
Mariana Laura Nistor ◽  
Tim Willans
Keyword(s):  
Development Plan ◽  
Field Development

The Impact of Overbalanced Drilling From Exploration/Appraisal Wells to Field Development Plan

2021 ◽  
Vol 62 (6) ◽  
pp. 694-710
Author(s):  
Mohammadhossein Mohammadlou ◽  
◽  
Matthew Guy Reppert ◽  
Roxane Del Negro ◽  
George Jones ◽  
...  
Keyword(s):  
Development Plan ◽  
Core Material ◽  
Reservoir Quality ◽  
Field Development ◽  
The Core ◽  
Well Design ◽  
Well Data ◽  
The Impact ◽  
Initial Exploration

During well planning, drillers and petrophysicists have different principle objectives. The petrophysicist’s aim is to acquire critical well data, but this can lead to increased operational risk. The driller is focused on optimizing the well design, which can result in compromised data quality. In extreme cases, the impact of well design on petrophysical data can lead to erroneous post-well results that impact the entire value-chain assessment and decision making toward field development. This paper presents a case study from an Upper Jurassic reservoir in the Norwegian Sea where well design significantly impacted reservoir characterization. Three wells (exploration, appraisal, and geopilot) are compared to demonstrate the impact of overbalanced drilling on both log and core data. Implications for reservoir quality assessment and volume estimates are discussed. Extensive data collection was initially carried out in both exploration and appraisal wells, including full sets of logging while drilling (LWD), wireline logging, fluid sampling, and extensive coring. Both wells were drilled with considerable overbalanced mud weights due to the risk of overpressured reservoirs in the region. The log data were subsequently corrected for significant mud-filtration and fines invasion, with calibration to core measurements guiding the interpretation. A thorough investigation of core material raised suspicion that there could also be significant adverse effects on core properties resulting from overbalanced drilling. The implications were so significant for the reservoir volume that a strategic decision was made to drill a geopilot well close to the initial exploration well prior to field development drilling. The well was drilled 6 years after the initial exploration phase with considerably lower overbalance. Extensive well data, including one core, were acquired. The recovered core was crucial in order to compare the reservoir properties for comparable facies between all three wells. The results from the core demonstrate distinctly different rock quality characteristics, especially at the high end of the reservoir quality spectrum. Results of the core study confirmed the initial hypothesis that overbalanced drilling had significantly impacted the properties of the core and well logs. This study shows how well design adversely affected petrophysical measurements and how errors in these data compromised geological and reservoir models, leading to a suboptimal field development plan that eroded significant value. This example provides a case study that can be used to improve well designs so that petrophysicists and drillers can both be part of the same value creation result.

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