Achieving Desired Fracture Placement in a Thick and Stratified Reservoir
- M. Jaboob (BP Oman) | G.A. Turk (BP Oman) | M. Rylance (BP Exploration) | R. Trejo (Schlumberger) | A. Al-Shueili (BP Oman) | A. Al Manji (BP Oman) | O.A. Ishteiwy (BP Oman)
- Document ID
- Society of Petroleum Engineers
- SPE International Hydraulic Fracturing Technology Conference and Exhibition, 16-18 October, Muscat, Oman
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 4.1 Processing Systems and Design, 4 Facilities Design, Construction and Operation, 3 Production and Well Operations, 2.2 Installation and Completion Operations, 2.4.1 Fracture design and containment, 4.1.2 Separation and Treating, 2.2.2 Perforating, 2.1.3 Completion Equipment, 2 Well completion, 5.8.1 Tight Gas, 2.5.2 Fracturing Materials (Fluids, Proppant), 5 Reservoir Desciption & Dynamics, 5.8 Unconventional and Complex Reservoirs, 2.4 Hydraulic Fracturing
- laminated, Hydraulic fracturing, thick reservoir, Proppant fracturing
- 3 in the last 30 days
- 149 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
The Barik formation is a low-permeability conventional tight-gas reservoir, in Block 61 in the Sultanate of Oman, comprised of a series of interbedded sandstone and mudstone (shale) layers. To achieve the most efficient and economic development of this formation sequence, the wells require the application of massive hydraulic fracturing. Such an approach was developed and deployed during the Appraisal stage of the programme and a considerable effort was placed in ensuring that the fracture height was contiguous, resulting in an effective drainage across all layers of the Barik formation. This approach was then encapsulated in the Full Field Development (FFD) planning Basis of Design (BoD) and was established as the approach to be taken throughout FFD.
Until the field development was well underway, a single fracture treatment had proven sufficient to stimulate the entire Barik reservoir. However, as the development moved into the Southern area of the field, a substantial thickening of the Barik sequence was encountered and with this change successful complete vertical propped fracture coverage became much more challenging to achieve in an effective and repeatable manner. This paper demonstrates the approaches that were subsequently taken with the fracture design, the fracturing fluid selection and the fracture perforation strategy to address this issue and restore the achievement of complete fracture/formation coverage.
Throughout the paper a number of examples will be presented that demonstrate the issues and effects that arose with the thickening of the Barik formation. The paper will then go on to examine how these effects were identified, what surveillance was used and the various characteristics that were displayed and how they were inferred. It will examine how the various issues were addressed, what changes were made to the fracturing strategy and demonstrate, through direct results, the outcomes that were subsequently achieved.
This paper will focus on some of the principal issues that can arise when moving a developing fracture BoD in a laminated sequence into a more thickly developed environment with more extensive height and bulkier sands. The paper will provide a number of detailed examples of the issues themselves, and describe the detrimental and impactful effects that they may have on fracture coverage and hence well productivity and EUR. Additionally, the paper will describe the approaches that can be used in order to successfully address these effects. The paper will clearly demonstrate that when such considerations are taken into account that a successful suite of outcomes can be achieved.
|File Size||2 MB||Number of Pages||21|
Al Rashdi, K. and Spain, D. (2015) Barik Reservoir Description - An Evolving Concept, presented at SPE MEUG Conf. and Exh., Muscat, Oman, 26–28 Jan, SPE-172912-MS https://doi.org/10.2118/172912-MS
Al Shueili, A M., Al Manji, A. and Rylance, M. (2016). Khazzan: Making the Most of the Fracturing Sweet-Spot Between Verticals and Horizontals. Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 9–11 February. SPE-179140-MS. https://doi.org/10.2118/179140-MS
Clark, R. A., Husain, A., and Rainey, S. (2015) Successful Post-Fracture Stimulation Well Cleanup and Testing of Tight Gas Reservoirs in the Sultanate of Oman. SPE MEUG Conf. and Exh., Muscat, Oman, 26-28 January, SPE-172957-MS, http://dx.doi.org/10.2118/172957-MS
Martins, J.P., Leung, K.H., Jackson, M.R., Stewart, D.R. and Carr, A.H. 1989. Tip Screen-Out Fracturing Applied to the Ravenspurn South Gas Field Development, presented at the SPE ATCE, San Antonio, Texas, USA, Oct 8-11, SPE 19766. http://dx.doi.org/10.2118/19766-PA
Rylance, M., Nicolaysen, A., Judd, T.C., Ishteiwy, O.A., Huey, T. and Giffin, W.J. 2011 Hydraulic Fracturing: Key to Effective Khazzan-Makarem Tight Gas Appraisal. SPE MEUG Conf. and Exh., Muscat, Oman, 31-January – 2 February. SPE-142783-MS http://dx.doi.org/10.2118/142783-MS
Rylance, M. and Giffin, W.J. (2011). Operational QA/QC: What You See is Not Necessarily What You Get. International Petroleum Technology Conference. IPTC-14184-MS http://dx.doi.org/10.2523/IPTC-14184-MS
Rylance, M., Judd, T.C. and Makmun, A. (2011). After Closure Analysis an Underutilized and Undervalued approach to Understanding kh. SPE Middle East Oil and Gas Show and Conf., Manama, Bahrain. SPE-141681-MS http://dx.doi.org/10.2118/141681-MS
Spain, D.R., Naidu, R., Dawson, W.. 2015 Integrated Workflow for Selecting Hydraulic Fracture Initiation Points in the Khazzan Giant Tight Gas Field, Sultanate of Oman. Presented at the Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, UAE, 9–12 November. SPE-177939-MS. https://doi.org/10.2118/177939-MS
Stiteler, T.C. and Shell, M.J.P., (2015) Predicting Barik Formation Production from Seismic, Khazzan Field, North Oman, presented at the SPE MEUR Conference and Exhibition, Muscat, Oman, Jan 26–28. SPE-172964-MS http://dx.doi.org/10.2118/172964-MS