An Investigation of Vertical and Lateral Communication in an Unconventional Oil Reservoir Using Geochemistry and Reservoir Simulation

Rasdi, Mohd; Salman, Ahmad; Adams, D.M.; Sofer, Zvi

doi:10.2118/162673-ms

Cited by 8 publications

(5 citation statements)

References 12 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…This will give an insight into the vertical interference between layers as described by Rasdi et al (2012). Four wells are completed in Middle Bakken and another four are completed in Three Forks.…”

Section: Model 2: Heterogeneous Case -Thirty-stage Horizontal Wellsmentioning

confidence: 96%

“…The hydraulic fracture, micro-fracture, and matrix properties were obtained from production data analysis, detailed fracture characterization study, and core permeability measurements from the study area (Rasdi et al, 2012). In both models, the dual-porosity is a system where the flow path in the stimulated reservoir region begins with the nano-scale matrix flow to natural fractures to hydraulic fracture and to the wellbore.…”

Section: Simulation Modelingmentioning

confidence: 99%

“…A heterogeneous model upscaled from the discrete fracture network model (Rasdi et al, 2012) was further used in the study to simulate similar scenarios with the homogeneous model. A detail fracture characterization was constructed in this model to understand the lateral and vertical well connectivity.…”

Section: Model 2: Heterogeneous Casementioning

confidence: 99%

See 2 more Smart Citations

Evaluating Long Term Flow Regimes in Unconventional Oil Reservoirs with Diverse Completion Technology

et al. 2013

View full text Add to dashboard Cite

Innovative completion techniques for unconventional oil and gas reservoirs have been developed at a rapid pace. Deciphering the flow regime characteristics of the pressure-time signature of flowing wells associated with these new completion techniques is critical for evaluating well performance and ultimate hydrocarbon recovery. In this paper we present the flow regimes observed in the plots of field production data for several of these new completion techniques. We also present the simulated model results for these completions.Several rate-transient analyses (RTA) for different well completion techniques from 1990 to 2010 were analyzed to determine how different completion techniques would affect flow regime characteristics-specifically, the linear flow period. Reservoir simulation results for homogenous and heterogeneous reservoirs showed that hydraulic fracture and natural fracture properties are the most crucial variables affecting the linear flow period. A statistical analysis of the Arp's decline b-factor was also used to show the impact of increased reservoir connectivity with advanced completion techniques and stimulation. This paper demonstrates that (a) completion techniques can influence the linear flow period and the length of the transition period before boundary-dominated flow prevails, and (b) different completion techniques lead to different flow regime diagnostics and different Arp's flow rate exponent b.

show abstract

Section: Model 2: Heterogeneous Case -Thirty-stage Horizontal Wellsmentioning

confidence: 96%

Section: Simulation Modelingmentioning

confidence: 99%

See 1 more Smart Citation

Evaluating Long Term Flow Regimes in Unconventional Oil Reservoirs with Diverse Completion Technology

et al. 2013

View full text Add to dashboard Cite

show abstract

“…Ceramic proppant provides not only greater crush resistance but also allows for higher conductivity (Rankin et al 2010;Terracina et al 2010). Closure stress as determined during a DFIT was recommended to refine the proppant selection further and determine whether a different-strength proppant would be more appropriate.…”

Section: Pre-2009 South Antelope Field Completionsmentioning

confidence: 99%

Optimized Production in the Bakken Shale: South Antelope Case Study

West¹,

Harkrider²,

Besler³

et al. 2014

SPE Drilling &Amp; Completion

View full text Add to dashboard Cite

Focused modifications in drilling, reservoir, and completion engineering from 2009 to the present have improved Bakken, specifically the South Antelope field, production as much as 50 to 75%. To achieve these results, Helis Oil and Gas Company formed a multidisciplinary team in 2008 that was tasked with evaluating and overhauling its completion approach. Pre-2008 completions followed conventional wisdom: Target the Middle Bakken formation between the Lodge Pole and the Three Forks formations. Pre-2009 wellbore constructions included "kick outs" (i.e., multilaterals); openhole completions; short laterals; single-stage ported subs; sliding sleeves; and long stage intervals; and they were erratic and inconsistent. The designs and procedures resulted in a high percentage of premature screenouts. In addition, the production responses on these Middle Bakken completions averaged 330 BOPD with an estimated ultimate recovery (EUR) of 300,000 bbl of oil equivalent. During the pre-2009 period, three Three Forks were completed, and these wells produced, on average, 550 BOPD. After evaluating the pre-2009 results, the team recommended ten Changes: (1) change landing target to the Three Forks; (2) increase lateral lengths approximately two-fold from short laterals ("640s") to long laterals ("1280s"); (3) increase formation contact (completion method, stage lateral length, and perforation spacing/density); (4) refine pumpdown operations; (5) implement critical-fracturingmechanism diagnosis; (6) incorporate proppant selection (ceramic vs. sand); (7) refine flush procedure to include monitoring and ensure consistency; (8) integrate on-site, real-time pressure management and proppant schedule including proppant slugs, altered mesh types, and adjusted ramp schedule; (9) adjust treatment-fluid design (25-lbm gel loading instead of 40-lbm gel loading); and (10) implement flowback and flow-rate control. Implementing these recommendations, Helis deviated from conventional Williston Basin philosophy and drilled 30 "1280s" during 2010-2012. These wells resulted in approximately 1,500 BOPD with a maximum of 2,500 BOPD and EURs of approximately 1.2 million BOE. They are among the best wells in the Williston basin. In comparison, directoffset-well EURs averaged less than 750,000 BOE. The success of these wells is not the result of one breakthrough but rather the result of sound changes to engineering techniques that were carried out systematically. Applying these engineering practices, maintaining strict adherence to recommended practices, and not making dramatic, unfounded changes ultimately optimized production in this Bakken project.

show abstract

“…1. Rasdi et al (2012) explores the vertical and lateral communication in the Bakken and found that the bounding layers can contribute to production with a superior completion method and or presence of through-going natural fractures. Connectivity between layers provides an opportunity to further investigate the correlation between observed field water cut and initial water saturation.…”

Section: Introductionmentioning

confidence: 99%

Analyzing Completion Efficiency Using Modified Heterogeneity Index

Salman

Chen

Rasdi

2013

SPE Annual Technical Conference and Exhibition

Self Cite

View full text Add to dashboard Cite

Completion techniques in the unconventional reservoirs are continuously evolving. Yet a method to evaluate completion efficiency is still lacking. This study proposes a method employing the conventional Modified Heterogeneity Index (MHI) to evaluate completion competency and reservoir quality.Hydraulic fracturing is designed to maximize reservoir contact. The hydraulic fractures may grow beyond the target or landed geologic zones due to an improperly planned or executed stimulation. This paper first shows the vertical water saturation profile and the observed correlation between water saturation and water cut. These results help to understand reservoir communication between multiple stacked reservoirs and hence help to quantify completion effectiveness.Modified Heterogeneity Index is traditionally used in conventional reservoirs to monitor water breakthrough and normalize producer well performance in a water-flood field. This paper proposes a method to exploit the HI analyses and understand the correlation between water production and well productivity. The analysis is also tied to completion techniques to understand completion efficiency and its relation to reservoir properties. This paper demonstrates that (a) correlation between water saturation, water cuts and production indicates that water saturation is one of the key reservoir properties governing production, (b) modified Heterogeneity Index can be utilized to scrutinize the completion effectiveness and reservoir quality, (c) the new method can be used pro-actively to screen for refrac candidates and to forecast or estimate the possibility of pressure communication between offset wells.

show abstract

An Investigation of Vertical and Lateral Communication in an Unconventional Oil Reservoir Using Geochemistry and Reservoir Simulation

Cited by 8 publications

References 12 publications

Evaluating Long Term Flow Regimes in Unconventional Oil Reservoirs with Diverse Completion Technology

Evaluating Long Term Flow Regimes in Unconventional Oil Reservoirs with Diverse Completion Technology

Optimized Production in the Bakken Shale: South Antelope Case Study

Analyzing Completion Efficiency Using Modified Heterogeneity Index

Contact Info

Product

Resources

About