Geomechanical modeling using the depth-of-damage approach to achieve successful underbalanced drilling in the Gulf of Suez rift basin

Abdelghany, Wael K.; Radwan, Ahmed E.; Elkhawaga, Mohamed A.; Wood, David A.; Sen, Souvik; Kassem, Abdel Meguid

doi:10.1016/j.petrol.2020.108311

Cited by 63 publications

(14 citation statements)

References 63 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…et al 2019b, 2020aKassem et al 2021). Hermina et al (1989) Abdelghany et al 2020;Radwan 2020a, b, c;Radwan et al 2020a, b). The Middle to Upper Serravallian Belayim Formation, which is the most important syn-rift oil reservoirs, is unconformably underlain by the Kareem Formation and its contact with the overlying South Gharib Formation is a disconformity.…”

Section: Lithostratigraphy and Geologic Settingmentioning

confidence: 99%

Implementation of Rock Typing on Waterflooding Process During Secondary Recovery in Oil Reservoirs: A Case Study, El Morgan Oil Field, Gulf of Suez, Egypt

et al. 2021

Self Cite

View full text Add to dashboard Cite

Waterflooding is one of the most common secondary recovery methods in the oil and gas industry. Globally, this process sometimes suffers a technical failure and inefficiency. Therefore, a better understanding of geology, reservoir characteristics, rock typing and discrimination, hydraulic flow units, and production data is essential to analyze reasons and mechanisms of water injection failure in the injection wells. Water injection failure was reported in the Middle Miocene Hammam Faraun reservoir at El Morgan oil field in the Gulf of Suez, where two wells have been selected as injector’s wells. In the first well (A1), the efficiency of injection was not good, whereas in the other analog A2 well good efficiency was assigned. Therefore, it is required to assess the injection loss in the low efficiency well, where all aspects of the geological, reservoir and production data of the studied wells were integrated to get a complete vision for the reasons of injection failure. The available data include core analysis data (vertical and horizontal permeabilities, helium porosity, bulk density, and water and oil saturations), petrographical studies injection and reservoir water chemistry, reservoir geology, production, and injection history. The quality of the data was examined and a set of reliable X–Y plots between the available data were introduced and the reservoir quality in both wells was estimated using reservoir quality index, normalized porosity index, and flow zone indicator. Integration and processing of the core and reservoir engineering data indicate that heterogeneity of the studied sequence was the main reason for the waterflooding inefficiency at the El Morgan A1 well. The best reservoir quality was assigned to the topmost part of the reservoir, which caused disturbance of the flow regime of reservoir fluids. Therefore, it is clearly indicated that rock typing and inadequate injection perforation strategy that has not been aligned with accurate hydraulic flow units are the key control parameters in the waterflooding efficiency.

show abstract

Section: Lithostratigraphy and Geologic Settingmentioning

confidence: 99%

Implementation of Rock Typing on Waterflooding Process During Secondary Recovery in Oil Reservoirs: A Case Study, El Morgan Oil Field, Gulf of Suez, Egypt

et al. 2021

Self Cite

View full text Add to dashboard Cite

show abstract

“…The Gulf of Suez is rich in oil and gas fields [50][51][52][53][54][55][56][57][58][59][72][73][74][75], and the Sidki is located in the southern part of the basin, close to significant oil and gas fields. The geological description of the Sidki field presented in Sect.…”

Section: Geological Characterization Of the Nubian 'C' Reservoirmentioning

confidence: 99%

Reservoir Formation Damage; Reasons and Mitigation: A Case Study of the Cambrian–Ordovician Nubian ‘C’ Sandstone Gas and Oil Reservoir from the Gulf of Suez Rift Basin

et al. 2021

Self Cite

View full text Add to dashboard Cite

Reservoir formation damage is a major problem that the oil and gas industry has to mitigate in order to maintain the oil and gas supply. A case study is presented that identifies the impacts of formation damage and their causes in the Nubian ‘C’ hydrocarbon reservoir within Sidki field located in the Southern Gulf of Suez, Egypt. In addition, a formation damage mitigation program was designed and implemented involving an effective stimulation treatment for each well experiencing reservoir damage. The data available for this study include core analysis to provide rock mineralogy and lithology; analysis of production fluid data; water chemistry; drilling fluid composition; perforations and well completion details; workover operations; and stimulation history. The diagnosis of formation damage based on the integrated assessment of the available data is associated with several benefits, (1) The integration of the data available helps provide a robust analysis of formation damage causes and in establishing suitable remediation actions, (2) Workover fluid is confirmed as the primary cause of reservoir damage in the studied well, (3) Several reservoir damage mechanisms were identified including water blockage, solids and filtrate invasion, fluid/rock interaction (deflocculation of kaolinite clay), salinity shock and/or high-sulfate content of the invaded fluid, (4) Irrespective of the potential causes of formation damage, the primary objective of a gas production company is to mitigate its effects and the integrated dataset helps to design appropriate and effective stimulation treatments to overcome formation damage, and (5) In gas reservoirs, especially low permeability ones, extra precautions are necessary to avoid potential reservoir damage due to workover fluid invasion.

show abstract

“…where Pp g is the pore pressure gradient in ppg, φ d is the hydrostatic pore pressure gradient in ppg, OBG is the overburden gradient in ppg, DT and R denote the compressional sonic slowness in µs/ft and deep resistivity logs in oms meter, respectively. DT n and R n are the sonic and resistivity log responses against the normally compacted shale zones (Abdelghany et al 2021). In addition to oil-based muds, two types of water-based muds can be utilized while drilling in salt regions.…”

Section: Modeling Pore Pressure In Underbalanced Drilling Operationmentioning

confidence: 99%

Validation of analytical model and identification of salt effect on wellbore temperature in underbalanced drilling

Olayiwola

Nguyen

Bello

et al. 2021

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

Understanding the behavior of the borehole temperature recovery process, which influences drilling operations, requires an adequate estimation of fluid temperature. The presence of salt in a saline formation changes the composition of the annular fluid and has a significant impact on the fluid temperature distribution during drilling operations. As a result, while drilling a saline formation, it is vital to examine the key parameter that determines an accurate estimate of fluid temperature. Using python software and statistical quantitative methods, this study proposes a simplified user-friendly computational system that analyzes the drilling fluid systems performance evaluation and selection optimization.The fluid temperature distribution of X Field in China was analyzed using Shan mathematical model as a base model. When compared to MWD data from the field, the model predicted the temperature distribution of the field with less than 10% error. An adjustment factor was introduced to the base model to accommodate for changes in annular fluid composition while drilling a saline formation. The findings show that salt concentration has an impact on fluid temperature distribution during drilling. The fluid temperature at the wellbore condition changes by at least 7% with both high and low adjustment factors. Because the salt in the formation inflow dissolves in the drilling fluid near the annulus, the rheology of the fluid combination changes.

show abstract

Geomechanical modeling using the depth-of-damage approach to achieve successful underbalanced drilling in the Gulf of Suez rift basin

Cited by 63 publications

References 63 publications

Implementation of Rock Typing on Waterflooding Process During Secondary Recovery in Oil Reservoirs: A Case Study, El Morgan Oil Field, Gulf of Suez, Egypt

Implementation of Rock Typing on Waterflooding Process During Secondary Recovery in Oil Reservoirs: A Case Study, El Morgan Oil Field, Gulf of Suez, Egypt

Reservoir Formation Damage; Reasons and Mitigation: A Case Study of the Cambrian–Ordovician Nubian ‘C’ Sandstone Gas and Oil Reservoir from the Gulf of Suez Rift Basin

Validation of analytical model and identification of salt effect on wellbore temperature in underbalanced drilling

Contact Info

Product

Resources

About