Multilateral stimulation technology as an alternative to hydraulic fracturing for carbonate reservoirs with thin oil rims

The paper considers Multilateral Stimulation Technology, a wellbore stimulation technology designed to enhance oil recovery in carbonate reservoirs with low vertical permeability and low effective oil pay. The purpose of the study is to analyze Multilateral Stimulation Technology efficiency in reservoirs with oil rims thinner than 5 m in highly heterogeneous and fractured rock conditions. The object of research is horizontal and directional wells equipped with radial formation drilling system using retractable needles. The subject of the study is technological features of Multilateral Stimulation Technology application including modifications involving acidizing of the rock ahead of the nozzle and mechanical drilling with turbine-driven mini-bits. The research methods include field data analysis, a review of international and domestic experience, interpretation of field results, as well as a comparative assessment with traditional hydraulic fracturing. The mechanisms of radial laterals formation, the influence of geological factors on technology efficiency, and filtration process modeling features are examined. The study results demonstrate that Multilateral Stimulation Technology provides a controlled increase in reservoir drainage volume, reduces the risk of water and gas breakthrough, and increases well productivity by 2–4 times compared to untreated wells. Acid activation and turbine drilling significantly increase the penetration depth and stability of lateral channels. The technology was found to be most effective in carbonate reservoirs with permeability of 0.1–10 mD and a low Kv/Kh ratio. It is concluded that Multilateral Stimulation Technology represents a promising alternative for developing thin oil rims and hard-to-recover reserves in the Russian Federation, offering a controlled substitute for conventional hydraulic fracturing.

1. Ashirov K.B., Vyzhigin G.B. Evaluation of the efficiency of hydrochloric acid treatment of wells in carbonate reservoirs. Oil Industry. 1977;7:28-31. Available from: https://www.oil-industry.net/Journal/archive_detail.php?art=108219 [Accessed 23th January 2026]. (In Russ.).

2. Mukhametshin V.Sh. Dependence of oil recovery factor on well spacing in the development of low-productivity carbonate reservoirs. Oil Industry. 1989;12:26-29. Available from: https://oil-industry.net/Journal/archive_detail.php?ID=8155andart=122334 [Accessed 23th January 2026]. (In Russ.).

3. Manchanda R., Sharma M.M. Impact of completion design on fracture complexity in horizontal shale wells. SPE Drilling and Completion. 2014;29(1):10-21. Available from: https://onepetro.org/DC/article-abstract/29/01/78/205825/Impact-of-Completion-Design-on-Fracture-Complexity?redirectedFrom=fulltext [Accessed 23th January 2026].

4. Hognesen E.J., Strand S., Austad T. Waterflooding of preferential oil-wet carbonates – oil recovery related to reservoir temperature and brine composition (SPE94166). In: 67th EAGE Conference and Exhibition. 2005;1-9. https://doi.org/10.3997/2214-4609-pdb.1.D026.

5. Olson K.E., Olsen E., Haidar S., Boulatsel A., Brekke K. Valhall field: horizontal well stimulations “Acid vs. Proppant” and best practices for fracture optimization. In: SPE Annual Technical Conference and Exhibition, Proceedings-Mile High Meeting of the Minds. 5–8 October 2003, Denver. Denver: Society of Petroleum Engineers, Inc.; 2003, р. 2947-2963. https://doi.org/10.2118/84392-ms. EDN: PJGXOR.

6. Suchkov B.M. Reasons of well productivity decrease. Oil Industry. 1988;5:52-54. Available from: https://oil-industry.net/Journal/archive_detail.php?ID=8143andart=6656 [Accessed 23th January 2026]. (In Russ.).

7. Rice K., Jorgensen T. Waters J.W. First installation of efficient and accurate multilaterals stimulation technology in carbonate oil application. SPE-171021-MS. 2014;1-15. https://doi.org/10.2118/171021-MS.

8. Freyer R., Stang A., Dusterhoft D., Meyer J., Røste T., Haug K. Multilateral stimulation technology. SPE-121814. 2009:1-14. Available from: https://onepetro.org/SPEEFDC/proceedings-abstract/09EFDC/09EFDC/SPE-121814-MS/146381?redirectedFrom=PDF [Accessed 24th January 2026].

9. Bagheri M., Settari A. Modeling of geomechanics in naturally fractured reservoirs. SPE Reservoir Evaluation and Engineering. 2008;11:108-118.

10. Moinfar A., Varavei A., Sepehrnoori K., Johns R.T. Development of an efficient embedded discrete fracture model for 3D compositional reservoir simulation in fractured reservoirs. SPE Journal. 2014;19(2):289-303. https://doi.org/10.2118/154246-PA. [Accessed 23th January 2026].

11. Panfili P., Jomaa A., Lydon S., McClure M., Cazeneuve E., Lee S. EDFM Workshop Proceedings. Houston; 2013, 20 p.

12. Khasanov G.V. Overview of Fishbones AS technology – improving reservoir connectivity. Kazan: Tatburneft; 2019, 65 p. (In Russ.).

13. Al-Khelaiwi F.T., et al. Radial drilling and reservoir performance. SPE Journal. 2008.

14. Economides M.J., Hill A.D., Ehlig-Economides C., Zhu Ding. Petroleum production systems. Sugarhouse Book Works. 2012.

15. Mukhametshin V.V., Andreev A.V., Kotenev Yu.A. Productivity forecast for deposits in carbonate reservoirs with hard-to-recover reserves. SOCAR Proceedings. 2016;3:40-45. (In Russ.). https://doi.org/10.5510/OGP20160300287.

16. Fishbones A.S. Multilateral stimulation technology manual. Stavanger; 2015, 110 p.

17. Al-Kobaisi, M., Kazemi, H., Ramirez, B., Ozkan, E., and Atan, S. A critical review for proper use of water/oil/gas transfer functions in dual-porosity naturally fractured reservoirs: Part II. SPE Reservoir Evaluation and Engineering. 2009;12:211-217.

18. Nasr-El-Din H.A., Domen M.V., Sierra L., Welton T. Optimization of surfactant-based fluids for acid diversion. SPE Journal. 2007;12(3):311-320. https://doi.org/10.2523/107687-MS.

19. Babadagli T., Al-Salmi S. A review of permeability-prediction methods for carbonate reservoirs using well-log data. SPE Reservoir Evaluation and Engineering. 2004;7(2):75-88. https://doi.org/10.2118/87824-PA.

20. Neylon K., Reiso E., Holmes J.A., Nesse O.B. Modeling well inflow control with flow in both annulus and tubing. In: Paper SPE 118909 presented at the SPE Reservoir Simulation Symposium, The Woodlands. 2–4 February, 2009, Texas. Texas; 2009. https://doi.org/10.2118/118909-MS.

21. Gomari K.A.R., Karoussi O., Hamouda A.A. Mechanistic study of water–rock interaction. SPE Journal. 2006;11(4):421-429.

22. Fredd C.N., Fogler H.S. Influence of transport and reaction on wormhole formation in porous media. AIChE Journal. 1998;44(9):1933-1949. https://doi.org/10.1002/aic.690440902.

23. Hoefner M.L., Fogler H.S. Pore evolution and channel formation during flow and reaction in porous media. AIChE Journal. 1988;34(1):45-54. https://doi.org/10.1002/aic.690340107.

24. Valko P., Economides M. Hydraulic fracture mechanics. Texas: Wiley; 1995, 298 р.

25. Babadagli T., Sultan Q.U. Scaling of cocurrent and countercurrent capillary imbibition for surfactant and polymer injection in naturally fractured reservoirs. SPE Journal. 2001;6:465-478. https://doi.org/10.1306/A9673446-1738-11D7-8645000102C1865D.