Central Oman

Study Details Strategy of Bottom-Up Water injection in a Heavy Oil Reservoir

Journal of Petroleum TechnologyApril, 2023

The G field is on the eastern flank of the South Oman Salt Basin 700 km south of Muscat. The main producing reservoir, the Mahwis sand of the Haima group, culminates in two accumulations (G Main and G East). The Mahwis formation is composed of clastic sediments interlayered with several cemented zones, which often act as baffles in some areas (Fig.

Journal of Petroleum Technology

asia government, bitumen, bottom-up water injection, complex reservoir, enhanced recovery, heavy oil field, heavy oil reservoir, oil sand, oman government, study detail strategy, Upstream Oil & Gas, water management, waterflooding

Country:

Asia > Middle East > Oman > Muscat Governorate > Muscat (0.31)
Asia > Middle East > Oman > Central Oman (0.31)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.54)

Oilfield Places: Asia > Middle East > Oman > Central Oman > South Oman Salt Basin > Mahwi Formation (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)

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15 Years of Foamed Cementing in Oman: Future Applications and Lessons Learned from 270+ Foamed Cementing Operations

Al Sulaimi, Zahra (Halliburton) | Al Adhali, Sara (Halliburton) | Austin, Jamie (Halliburton)

OnePetroOctober, 2022

Abstract For more than 15 years, foamed cementing has been deployed on wells drilled in the Fahud and Natih fields of North Oman. The production section targets the Natih formation, a fractured Mesozoic hydrocarbon-bearing carbonate sealed by the Fiqa above and the Nahr Umr shale below. The Natih carbonate characteristically requires a cementing design to cure losses while providing zonal isolation. Foamed cement is the standardized cement design used to meet this objective. Previous attempts to mitigate lost circulation during cement placement using conventional lost-circulation materials were attempted with little success. Since 2006, the advent of foamed cementing has been prescribed as the standard design for cement placement across the 8 1/2-in. production section. These wells have experienced an evolution of stage tools as well as liner packers to aid isolation. The cementing operation consists of a decision tree design approach based on the tools used on the 9 5/8-in. section as well as the quality of wellbore returns observed during cement delivery. The initial stage consists of nitrified water with a foaming agent intended to reduce the hydrostatic burden observed on the fractured formations. This is followed by a four-stage "filler" of foam cement, each with a specific nitrogen rate necessary to maintain the designed density at the final placement depth. If wellbore returns are stable throughout the "filler" phase, the nitrogen rate is reduced to target an ideal final cement density to help ensure the cement sheath has optimized sealant capabilities across the section objective. If wellbore returns are unstable, the final nitrogen stages are maintained, and emphasis is placed on finalizing displacement and choking the backside, as necessary, to maintain foam expansion. Approximately 270 foamed cement applications were executed in the field using this approach. The acceptance criteria target for this section is for returns to be observed at the surface during cement displacement before packer installation. Continuous lessons learned on design parameters necessary to achieve the objective were captured in the 15-year period discussed. The value added using stage tools versus liner packers was measured and the base slurry designed used for the foam has been modified over time to deliver the highest probability of success for these wells. Designed cement properties were evaluated and optimized over the 15-year period of foamed cement delivery. Improvement to cement hydration analysis (CHA), permeability, transition time, and expansion slurry properties are discussed. Additionally discussed, as losses continue to be challenging across these sections, a variation of 11-kPa/m ultra-lightweight foamed slurry designed for wells in the Fahud and Natih production sections are an alternative option for extreme losses observed at > 5 m/hr before cementing.

OnePetro

doi: 10.2118/211510-MS

SPE

SPE-211510-MS

ADIPEC

Country:

Asia > Middle East > Oman > Central Oman (0.25)
Asia > Middle East > Oman > Ad Dhahirah Governorate (0.24)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Oman > Central Oman > South Oman Salt Basin > Nahr Umr Formation (0.99)
Asia > Middle East > Oman > Ad Dhahirah Governorate > Fahud Salt Basin > Natih Field (0.92)
Asia > Middle East > Oman > Ad Dhahirah Governorate > Fahud Salt Basin > Fahud Field (0.92)

SPE Disciplines: Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)

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New Iterative Resistivity Modelling Workflow Reduces Uncertainty in the Assessment of Water Saturation in Deeply-Invaded Reservoirs

OnePetroJune, 2022

Abstract A new iterative modelling workflow has been designed to reduce uncertainty of water saturation (Sw) calculations in the tight Barik sandstone in the Sultanate of Oman. Results from this case study indicate that Sw can be overestimated by up-to twenty saturation units if the as-acquired deep resistivity is used in volumetric calculations. Overbalanced drilling causes deep invasion of waterbased mud (WBM) filtrate into porous and permeable rocks, leading to radial displacement of in-situ saturating fluids away from the wellbore. In low-porosity reservoirs drilled with WBM the inability of the filtration process to quickly build impermeable mudcake translates into long radial transition zones. Under certain reservoir and drilling conditions, deep resistivity logs cannot reliably measure true formation resistivity and are therefore unable to provide an accurate assessment of hydrocarbon saturation. The effect of mud-filtrate invasion on resistivity logs has been extensively documented; processing techniques utilize resistivity inversion and tool-specific forward modeling to provide uninvaded formation resistivity logs which are much better suited for in-place resource volume assessment. However, sensitivity analysis shows that the accuracy of invasion-corrected logs dramatically decreases as the depth of invasion increases whereby the inversion process needs to be further constrained. The new workflow is designed to reduce the nonuniqueness of true formation resistivity models, so that they honor multiple and independent petrophysical data. The inversion routine utilizes a Bayesian algorithm coupled with Markov-Chain Monte Carlo (MCMC) sampling. Inversion results are iteratively modified based upon two rock property models: one derived from rock-core data (helium expansion porosity and Dean-Stark saturations), and the other using an equivalent log interpretation of thick reservoir intervals from oil-based mud (OBM) wells. Simulated borehole-resistivity are compared to field logs after each validation loop against rock property models. The new inversion-based workflow is extensively tested in the unconventional tight Barik formation across water-free hydrocarbon and perched water intervals and inversion-derived Sw models are independently validated by capillary pressure-derived saturation-height models and fluid inflow rate from production logs.

OnePetro

doi: 10.30632/SPWLA-2022-0057

SPWLA

SPWLA-2022-0057

SPWLA 63rd Annual Logging Symposium

Country:

North America > United States (1.00)
Asia > Middle East > Oman > Central Oman (0.24)

Genre: Personal > Honors (0.93)

Geophysics: Geophysics (1.00)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Middle East > Oman > Central Oman > Barik Formation (0.98)

SPE Disciplines: Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)

Technology:

Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning (0.55)
Information Technology > Artificial Intelligence > Machine Learning > Learning Graphical Models (0.34)

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Approach Optimizes Post-Fracturing Cleanup and Testing

Journal of Petroleum TechnologyMay, 2022

The oil and gas industry currently faces the dual challenge of meeting the global energy demand with minimal carbon footprint. The Barik formation is a tight to low-end conventional reservoir in the Khazzan/Ghazeer field in central Oman. The field requires hydraulic fracturing to produce the wells economically. Each well requires a period of cleanup after pumping the chemicals and proppant into the formation for fracturing and before connecting it to the facility in order to keep all of the undesirable material from entering the processing facility. During this cleanup and testing period, all produced gas and condensate are flared in the atmosphere.

Journal of Petroleum Technology

Country:

Asia > Middle East > Oman > Ad Dhahirah Governorate (0.39)
Asia > Middle East > Oman > Central Oman (0.27)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Oman > Central Oman > Barik Formation (0.99)
Asia > Middle East > Oman > Ad Dhahirah Governorate > Arabian Basin > Rub' al-Khali Basin > Block 61 EPSA > Block 61 > Khazzan-Makarem Field > Khazzan Field > Miqrat Formation (0.94)
Asia > Middle East > Oman > Ad Dhahirah Governorate > Arabian Basin > Rub' al-Khali Basin > Block 61 EPSA > Block 61 > Khazzan-Makarem Field > Khazzan Field > Buah Formation (0.94)
(17 more...)

SPE Disciplines:

Production and Well Operations (1.00)
Health, Safety, Environment & Sustainability > Environment > Climate change (0.53)
Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (0.38)
(3 more...)

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A Comparative Analysis for Optimal Fracture Design Between the Crest and Flank Wells. Examples from Saih Rawl, Oman Tight Gas Field

Al Hinai, Adnan Saif (Petroleum Development Oman) | Abdelazim, Mohamed (Petroleum Development Oman) | Al Bahri, Khalfan (Petroleum Development Oman) | Al Suleimani, Ahmed Abdullah (Petroleum Development Oman) | Nunez, Alvaro Javier (Petroleum Development Oman) | Al Shekaili, Aadil Salim (Petroleum Development Oman)

OnePetroMarch, 2022

Abstract Saih Rawl gas is located in the South Oman Salt Basin. There are two main formations targeted for gas production; Barik & Miqrat Formations. These formations are tight and exhibit low permeability. In order to enhance gas production, these formations have to be hydraulically stimulated. The main objectives of this paper is to demonstrate the petrophysical properties of the hydraulically fractured zones. Assess gas flow contribution thru the individual zones measured by production logging and comparing with the amount of proppant placed in the formation. In addition, the paper discusses reservoir properties and characteristics obtained from logging, post stimulation operations results and post stimulation gas production. The paper discusses 20 wells; 10 from the crest and 10 from the flank. The two formations Barik and Miqrat cover approximately 17 sub reservoir units. The total overall placement ratio is 95% and 78% for the crest and flank respectively with 156 hydraulic stimulation stages. It was observed that five sub reservoir units proved to be challenging to place the desired proppant. The maximum operating pressure is reached before achieving the desired proppant concentration leading to a screen out; concentrations of 2 – 3 pounds per gallon. Petrophysical evaluation of porosity and permeability cross plots showed a linear relationship in the wells in the crest. While there was no clear relationship was seen in the flank. Radioactive tracers used are to understand if there is any proppant propergation into the higher or lower zones. Not all the five challenging sub reservoir units showed propergation to other units. The wells located in the crest showed a better production rate as compared to the flank. The paper highlights the importance of the using petrophysical evaluation to optimize hydraulic fracturing design for successful operations.

OnePetro

doi: 10.2118/200038-MS

SPE

SPE-200038-MS

SPE Conference at Oman Petroleum & Energy Show

Country: Asia > Middle East > Oman > Central Oman (0.36)

Genre: Research Report (0.54)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Oman > Central Oman > Barik Formation (0.99)
Asia > Middle East > Oman > Al Wusta Governorate > Ghaba Salt Basin > Saih Rawl Field > Miqrat Formation (0.99)
Asia > Middle East > Oman > Al Wusta Governorate > Ghaba Salt Basin > Saih Rawl Field > Barik Formation (0.99)
(2 more...)

SPE Disciplines:

Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)

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Conventional Tight Gas Field Through Unconventional Eyes: Data Analytics Help to Optimize Fracture Design and Operations

Yuan, Roger (Petroleum Development Oman) | Bahri, Khalfan (Petroleum Development Oman) | Veeken, Cornelis (Petroleum Development Oman) | Shoaibi, Sultan (Petroleum Development Oman)

OnePetroMarch, 2022

Abstract Deep tight gas fields in Northern Oman are often compared to and approached with unconventionals due to their tight matrix properties and the necessity of employing hydraulic fracturing to deliver productivity. Complicated by operational constraints and field histories, hydraulic fracture effectiveness – how fracture stimulation delivers relative to how much matrix flow contributes to production – remains a puzzle and a challenge. This further affects how to optimize existing completion and stimulation strategy in order to improve the value proposition. In this study, we review the fracture and production performance of a mature gas field in Northern Oman. Integrating data of various technical disciplines, we re-examine a wealth of cumulative field data over two decades of operations with an aim to identify the key enablers for fracture placement and production. With integration of reservoir properties, geomechanics, and time-lapse production profiles, we identify that geomechanics plays a key role in controlling reservoir fraccability and the placement of hydraulic fractures. While hydraulic fracture containment within the Barik formation has been well recognized and considered a given in multi-staged fractured vertical wells, the creation of fracture heights is found dependent on the in-situ stress conditions and pumping metrics, which further links to productivity. Such inter-relationship could potentially be utilized to optimize fracture performance by a refined placement strategy. With big data, the common technical opinions that normally arise from a deterministic approach on limited data can be better visualized and addressed. The statistical strength of the analysis leads to improved understanding of the subsurface complexity, interaction of reservoir quality with completion design, and a suite of future optimization opportunities.

OnePetro

doi: 10.2118/200138-MS

SPE

SPE-200138-MS

SPE Conference at Oman Petroleum & Energy Show

Artificial Intelligence, conventional tight gas field, data mining, enabler, fracture height, hydraulic fracture stimulation, hydraulic fracturing, inflow resistance, northern oman, optimize fracture design, production contribution, proppant placement, proppant tonnage, Reservoir Characterization, reservoir geomechanics, reservoir quality, reservoir transmissibility, tracer, Upstream Oil & Gas

Country: Asia > Middle East > Oman > Central Oman (0.49)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Oman > Central Oman > South Oman Salt Basin > Mahwi Formation (0.99)
Asia > Middle East > Oman > Central Oman > Barik Formation (0.99)
Asia > Middle East > Oman > Miqrat Formation (0.98)
Asia > Middle East > Oman > Al Wusta Governorate > Arabian Basin > Rub' al-Khali Basin > Barik Field > Barik Formation (0.98)

SPE Disciplines:

Well Completion > Hydraulic Fracturing (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)

Technology: Information Technology > Data Science (0.70)

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Hard Rock Horizontal Drilling—Using Mechanical Specific Energy, Downhole Vibrations Analysis, and Well Design to Optimize Performance

Heidari Varnamkhasti, Mohammad Reza (Schlumberger) | Al Hinaai, Qasim (Petroleum Development Oman) | Patil, Ravindra (Petroleum Development Oman) | Al Lawati, Ali Baqir (Schlumberger) | Al Ghasani, Rashid (Schlumberger) | Vasquez Bautista, Ramiro Oswaldo (Schlumberger)

OnePetroMarch, 2022

Abstract This paper presents a deep horizontal drilling campaign with the goal of eliminating several inefficiencies restricting the drilling performance, including downhole drilling bit or tool failures. The operator and the service company identified the inefficiencies by using engineering methods to overcome the challenges. Since 2013, the operator had been drilling horizontal wells with 600 to 1000 m of lateral targeting deep gas sandstone multilayer reservoirs with 15 to 35 kpsi unconfined compressive strength. The focus in the campaign will be from the kickoff point in the 8 3/8-in. section to the total depth (TD) of the well. Well-1 performance was greatly affected by the issues related to the wellbore instability in the build section, which dictated a change in the well program from the original fat to slim design. Later, other challenges and drilling inefficiencies resulted from this change, causing Well-6 design to be switched back to the original fat design to improve wellbore stability by having proper mud weight and other mud properties, bit and drive systems selection, as well as the drilling practices. Mechanical specific energy (MSE) is an industry recognized optimization tool to evaluate the drilling efficiency (Teale 1965) but it does not identify the sources of the inefficiencies (Chen 2019). The MSE, in addition to the downhole high-resolution drilling dynamics data, have been used to identify not only the drilling dysfunctions but also to help find the sources. This method supports the decisions for a change in the well design, bit, or the drilling practices, which in turn reduces the total number of runs and the downhole tool failures or damages. The improvements in drilling the horizontal wells since the campaign began are significant; i.e., Well-1 was drilled in approximately 165 days in 2014 while Well-6 was drilled in 49 days in 2017, which was 39 days ahead of the well plan with the majority improvements occurring in the last section. Well-6 is considered to be the most efficient Barik formation horizontal well drilled in Oman to date.

OnePetro

doi: 10.2118/200262-MS

SPE

SPE-200262-MS

SPE Conference at Oman Petroleum & Energy Show

BHA, borehole size, differential sticking, Directional Drilling, downhole vibration analysis, drilling dynamics, drilling operation, drilling parameter, horizontal well, impregnated bit, lateral section, mabrouk formation, mechanical specific energy, mud weight, reservoir, ROP, Upstream Oil & Gas, Well Design, well-6

Country: Asia > Middle East > Oman > Central Oman (0.25)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Oman > Central Oman > Barik Formation (0.99)
Asia > Middle East > Oman > Al Wusta Governorate > Ghaba Salt Basin > Saih Rawl Field > Miqrat Formation (0.99)
Asia > Middle East > Oman > Al Wusta Governorate > Ghaba Salt Basin > Saih Rawl Field > Barik Formation (0.99)
(2 more...)

SPE Disciplines: Well Drilling > Drilling Operations > Directional drilling (1.00)

Technology: Information Technology (0.34)

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Prediction of Reservoir Quality & Deliverability of the Tight Barik Formation in Khazzan Field, Oman

Al Rashdi, Khalil Ali (BP Exploration Co. Ltd) | Wells, Martin (BP Exploration Co. Ltd) | Clark, Nigel (BP Exploration Co. Ltd)

OnePetroNovember, 2021

Abstract The giant Khazzan gas field, located in onshore Oman, has been under development since 2013 and in production since 2017. The field is currently producing 1 billion cubic feet of gas per day from the Cambro-Ordovician Barik Formation. The 80-metre-thick paralic reservoir is 4.5 kilometers deep and has undergone complex stages of diagenesis, hydrocarbon charge and structural regime changes. Reservoir quality (RQ) is typically classed as tight (average porosity 6 porosity unit, average permeability 1 Milidarcy) but locally exceeds expectations given the burial history reaching up to 12 pu and 100 Milidarcy. This RQ variability and complexity makes reservoir deliverability (RD) a key uncertainty impacting the field development scheme and ultimately the projected economics. This study aims to create and test hypotheses of RQ and RD controls to reduce uncertainty in production and increase reservoir development efficiency. In order to better understand the key controls on reservoir quality, an extensive set of core, petrophysical log analysis and production data were integrated with field-wide seismic and outcrop data to update the Barik stratigraphic, structural and depositional frameworks. Extensive analytical techniques, including reservoir quality modelling, petrographic analysis, X-ray diffraction, mercury injection capillary pressure and minipermeameter data were also integrated. Quartz cementation and compaction are the principal degrading controls on reservoir quality. The controls on quartz cementation are complex and variably inter-related, although in general it is ductile content, proximity to mudstone and feldspar content that are the best predictors of porosity and permeability when convolved. Minipermeameter data confirms that distance to mudstone, or sandstone thickness, is an important control on reservoir quality. Using normalized gamma ray log data, total and mean individual sandstone thickness were calculated for every Barik well in Khazzan and compared to well dynamic behavior which demonstrated a positive correlation. Areas with high mean individual sandstone thickness and total sandstone thickness frequently equate with relatively high IP30s (average well production at 1100 psi well head pressure for 30 days). In contrast, areas with high total sandstone thickness, but low mean individual sandstone thickness may only have moderate IP30s as those sandstones may be more quartz cemented. Reservoir deliverability risk maps based on total and mean individual sandstone thickness and IP30 were constructed. These maps give insight into regions of poor and good gas deliverability and have identified areas that may be untested or undeveloped that may have potential upside. The resultant reservoir deliverability understanding of the Barik formation is consistent with depositional environment, diagenetic understanding and well performance. It is a good example of integrating diverse static and dynamic data to improve reservoir understanding and has direct business impact.

OnePetro

doi: 10.2118/208132-MS

SPE

SPE-208132-MS

Abu Dhabi International Petroleum Exhibition & Conference

Country:

Asia > Middle East > Oman > Central Oman (0.81)
Asia > Middle East > Oman > Ad Dhahirah Governorate (0.70)

Geologic Time:

Phanerozoic > Paleozoic > Cambrian (0.89)
Phanerozoic > Paleozoic > Ordovician > Lower Ordovician (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Oman > Central Oman > Barik Formation (0.99)
Asia > Middle East > Oman > Ad Dhahirah Governorate > Arabian Basin > Rub' al-Khali Basin > Block 61 EPSA > Block 61 > Khazzan-Makarem Field > Khazzan Field > Miqrat Formation (0.99)
Asia > Middle East > Oman > Ad Dhahirah Governorate > Arabian Basin > Rub' al-Khali Basin > Block 61 EPSA > Block 61 > Khazzan-Makarem Field > Khazzan Field > Buah Formation (0.99)
(6 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Sedimentology (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
(2 more...)

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How Different Are Ultrasonic Lab and Wireline Measurements in the Estimation of Dynamic Elastic Moduli?

Alkinani, H. H. (Missouri University of Science and Technology) | Al-Hameedi, A. T. (Missouri University of Science and Technology / American University of Ras Al Khaimah) | Dunn-Norman, S. (Missouri University of Science and Technology) | Aldin, M. (MetaRock Laboratories) | Govindarajan, S. (MetaRock Laboratories)

OnePetroJune, 2021

ABSTRACT: Acoustic measurements are vital for geomechanical applications to design safe mud weight window, estimating rock strength parameters, sand control, hydraulic fracturing, etc. There is usually a discrepancy between the ultrasonic lab and sonic log measurements due to the frequency difference and other measurement conditions. This work investigates the discrepancy between the ultrasonic lab measurements and sonic logs of both shear wave velocity (Vs) and compressional wave velocity (Vp) to understand the pivotal effect of these measurements on the accuracy of estimating dynamic moduli. Core samples for three zones (Nahr Umr shale, Zubair shale, and Zubair sandstone) in Rumaila field, Iraq, and well logs for the same sections were employed in this investigation. Single stage triaxial tests equipment used to measure Vp and Vs. Then, dynamic elastic rock properties were estimated using the data of ultrasonic lab and wireline measurements. The results illustrated that the readings of the velocities of sonic log waves are remarkably less than the measurements of the velocities of ultrasonic lab waves. This discrepancy can be explained due to the frequency in the laboratory to measure both dynamic wave velocities is too high when comparing it to the frequency of both dynamic wave velocities of the sonic log, besides other factors such as temperature and pressure conditions in the ambient lab and the downhole environments. For the laboratory (ultrasonic), the frequency is approximately one million hertz. However, for the sonic log, the frequency is approximately 20,000 hertz. Consequently, the estimations of the dynamic elastic moduli were tangibly different for both approaches. The least influenced elastic moduli by the discrepancy between sonic log and ultrasonic lab measurements was the bulk modulus (K). 1. Insights Into Elastic Wave Propagation in Rocks and Their Applications Elastic waves can be defined as mechanical disturbances that have the ability to propagate through a material. Besides, these waves have the potential to pass and travel over very long distances in sub-surface formations in order to obtain a piece of valuable information from portions of the zones that are usually unreachable. Elastic waves can be generated to be invested in applications such as seismic surveys, earthquakes, and rock mechanics. In water and air, the propagation of the elastic waves is commonly named acoustic waves, and the same concepts are predominantly utilized concerning waves in formations, as well. The velocity that is given by elastic stiffnesses and the density of the rock reflects the propagation of the elastic waves in rocks, and all those variables depend on others such as porosity. Consequently, the elastic waves have been employed as an efficient approach to estimate parameters by which specific formations in the field (Fjær et al., 2008).

OnePetro

ARMA

ARMA-2021-1409

55th U.S. Rock Mechanics/Geomechanics Symposium

core plug, discrepancy, elastic moduli, elastic wave, frequency, log analysis, Nahr Umr shale, Reservoir Characterization, s-wave velocity, shale, sonic log, ultrasonic lab measurement, Upstream Oil & Gas, well logging, zubair sandstone, zubair shale

Country:

Asia > Middle East > Iraq > Basra Governorate (0.35)
North America > United States > Texas > Harris County > Houston (0.28)
Asia > Middle East > Oman > Central Oman (0.26)

Geophysics: Geophysics > Seismic Surveying > Seismic Processing (0.38)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Oman > Central Oman > South Oman Salt Basin > Nahr Umr Formation (0.99)
Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Rumaila Field > Zubair Formation (0.99)
Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Rumaila Field > Shuaiba Formation (0.99)
(3 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)

Technology: Information Technology (0.34)

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A New Technique to Estimate Static Elastic Moduli From Multistage Triaxial Tests

Al-Hameedi, A. T. (Missouri University of Science and Technology / American University of Ras Al Khaimah) | Alkinani, H. H. (Missouri University of Science and Technology) | Dunn-Norman, S. (Missouri University of Science and Technology) | Aldin, M. (MetaRock Laboratories) | Govindarajan, S. (MetaRock Laboratories) | Guedez, A. (MetaRock Laboratories)

OnePetroJune, 2021

ABSTRACT: Static Young's modulus (E), Poisson's ratio (ν), bulk modulus (K), and maximum compressive strength (MCS) are among the most important parameters in rock mechanics. This work investigates a new approach to accurately estimate static E, ν, K, and MCS from multistage triaxial tests (MST) instead of single stage triaxial tests (SST) in case of having only MST data. Core samples from three zones; Zubair sandstone, Zubair shale, and Nahr Umr shale were obtained from the Rumaila field in Iraq. SST and four stages of MST for each formation were executed, and E, ν, K, as well as MCS, were acquired at each stage of MST and SST. The results showed that the average EMST from four stages of MST provided an underestimate of ESST for Nahr Umr shale and Zubair sandstone while the average EMST for Zubair shale provided an overestimate of ESST. Correction factors were proposed to calibrate the average EMST to ESST which are 1.127, 0.957, and 1.123 for Zubair sandstone, Zubair shale, and Nahr Umr shale, respectively. Average νMST resulted in an overestimate of νSST for Nahr Umr shale and Zubair sandstone while Zubair shale νMST provided an underestimate. Calibration factors were proposed for ν which are 0.645, 1.065, and 0.585 for Zubair sandstone, Zubair shale, and Nahr Umr shale, respectively. The averages of KMST and MCSMST provided an underestimate for KSST and MCSSST. Factors of 1.779, 1.35, and 1.458 were proposed for K for Zubair sandstone, Zubair shale, and Nahr Umr shale, respectively; and factors of 1.466, 1.446, and 1.358 were suggested for MCS for Zubair sandstone, Zubair shale, and Nahr Umr shale, respectively. These results can help to provide a good estimate of E, ν, K, and MCS from MST when the material is limited to perform SST. 1. Introduction Elastic moduli such as Young's modulus (E), Poisson's ratio (ν), and bulk modulus (K), as well as rock strength parameters such as uniaxial compressive strength (UCS), internal friction angle, and cohesion, are considered as major components of the mechanical characteristics of rocks. These parameters characterize the attitude of rock during loading and unloading conditions, which can be obtained in the laboratory by utilizing various tests (Peng and Zhang, 2007; Fjær et al., 2008). Knowing and understanding rock strength parameters will contribute to accurately estimating the in-situ stresses in sub-surface zones, which in turn this knowledge and comprehension will be a key for avoiding or mitigating the costly and time-consuming issues related to the exploration, completion, and production stages (e.g. wellbore instability and sand control) (Zoback et al., 2003; Zeynali, 2012; Wang and Sharma, 2017).

OnePetro

ARMA

ARMA-2021-1412

55th U.S. Rock Mechanics/Geomechanics Symposium

compressive strength, core plug, Iraq, mc sst, mechanical properties, MST, multistage triaxial test, Nahr Umr shale, Reservoir Characterization, reservoir geomechanics, shale, SST, sst result, triaxial test, underestimate, Upstream Oil & Gas, Wellbore Design, zubair sandstone, zubair shale

Country:

Asia > Middle East > Oman > Central Oman (1.00)
Asia > Middle East > Iraq (1.00)
North America > United States > Texas > Harris County > Houston (0.28)

Genre: Overview > Innovation (0.70)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff C Formation (0.99)
(10 more...)

SPE Disciplines:

Well Drilling > Wellbore Design (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)

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Collaborating Authors

Central Oman

Study Details Strategy of Bottom-Up Water injection in a Heavy Oil Reservoir

15 Years of Foamed Cementing in Oman: Future Applications and Lessons Learned from 270+ Foamed Cementing Operations

New Iterative Resistivity Modelling Workflow Reduces Uncertainty in the Assessment of Water Saturation in Deeply-Invaded Reservoirs

Approach Optimizes Post-Fracturing Cleanup and Testing

A Comparative Analysis for Optimal Fracture Design Between the Crest and Flank Wells. Examples from Saih Rawl, Oman Tight Gas Field

Conventional Tight Gas Field Through Unconventional Eyes: Data Analytics Help to Optimize Fracture Design and Operations

Hard Rock Horizontal Drilling—Using Mechanical Specific Energy, Downhole Vibrations Analysis, and Well Design to Optimize Performance

Prediction of Reservoir Quality & Deliverability of the Tight Barik Formation in Khazzan Field, Oman

How Different Are Ultrasonic Lab and Wireline Measurements in the Estimation of Dynamic Elastic Moduli?

A New Technique to Estimate Static Elastic Moduli From Multistage Triaxial Tests

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Collaborating Authors

Central Oman