Large Deployment of Multiphase Flowmeters in an Unconventional Field
- Bertrand Theuveny (Schlumberger) | Katharine Moncada (Schlumberger) | Melissa Roth (Schlumberger) | Yvette Wu (Schlumberger) | Michael Mikovich (Schlumberger) | Anna Guichard (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE Annual Technical Conference and Exhibition, 30 September - 2 October, Calgary, Alberta, Canada
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Multiphase flowmeter, back allocation, Eagle Ford, Unconventional, Production allocation
- 4 in the last 30 days
- 235 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 28.00|
The need for monitoring individual well production in unconventional fields is rising. The drivers are primarily related to accurate reporting for production allocation between wells. The main driver in North American operations for a meter-per-well flow rate monitoring has been the need for accurate per well production accounting due to the complexity of the land-owner interest.
There are additional benefits from the monitoring of early decline and determination of the transient evolution of the reverse productivity index (RPI) to evaluate the well performance. The availability of long-term rate transient data supports decline analysis and rate transient analysis, leading to better understanding of the estimated ultimate recovery (EUR), which may drive the selection of infill drilling locations. Finally, the identification of interference between flowing wells can help mitigate the issues of parent/child wells.
A specific case in the Eagle Ford is the systematic deployment of full gamma-spectroscopy multiphase flowmeters at well pads. This intelligent pad architecture consists of one multiphase flowmeter per well and a production manifold that enables commingling of the production to a single flowline connected to the inlet manifold of the production facility.
The rationale of the decision for the installation of such solution in lieu of a metering separator per well is based on the evaluation of the impact of this technology on capex and opex reductions.
Several lessons learned are provided. They include a discussion of the change management issues related to the installation of the meters, the modifications necessary to the production facility at the receiving side, and the data management and data analytics that were enabled from the gathering of systematic, continuous, and high-resolution measurements.
The impact of the installation of the meters in the field is noticeable and quantifiable. with several prior wells used as a benchmark. The effects are not limited to cost reduction, but also lead to an increase in production related to the release of operational crews from daily well testing tasks that used to be necessary. The data quality and coverage are also increased.
A few suggestions are made concerning optimization of the deployment and use of remote monitoring options for enhanced efficiency. Automated data workflows are also discussed.
The reduction of HSE risks through a better management of field operators is also assessed.
|File Size||765 KB||Number of Pages||10|
Alberta Energy Regulator, Directive 017. 2018. Measurement Requirements for Oil and Gas Operations. https://www.aer.ca/documents/directives/Directive017.pdf
Cramer, R., Schotanus, D., Ibrahim, K., Colbeck, N. 2011.Improving Allocation and Hydrocarbon Accounting Accuracy Using New Techniques. SPE Economics & Management Volume 3 Issue 04, October 2011. SPE-125178-PA. 10.2118/125178-PA
Darab, M., Nygaard, R., Singh, A. P. 2018. Early-Stage Detection of Scales in a Deepwater Field Offshore Ghana via Remote Monitoring of Multiphase Meter. Presented at the SPE Asia Pacific Oil & Gas Conference and Exhibition, Brisbane, Australia, 23-25 October. SPE-191960-MS. 10.2118/191960-MS
Deen, T., Daal, J. and Tucker, J. 2015. Maximizing Well Deliverability in the Eagle Ford Shale. Presented at the SPE Annual Technical Conference and Exhibition, Houston, Texas, 28-30 September. SPE-174831-MS. 10.2118/174831-MS
Falcone, G., & Harrison, B. 2011. Forecast expects continued multiphase flowmeter growth. Oil & Gas Journal, 109 (10), 68-73. https://www.ogj.com/articles/print/volume-109/issue-10/drilling-productioniforecast-expects-continued-multiphase-flowmeter-growth.html
Krupnik A., Asadollahi, A., Belausteguigoitia Rius, J. C., Hayes, K., Echarte, I., Gass, P., Echevarria, D. 2017. North American Energy Integration: Assessing Oil and Gas Policy Issues ahead of NAFTA Renegotiation, RFF report, https://media.rfforg/documents/RFF-Rpt-NA200i120and20GasNAFTA.pdf
Lu, H., Anifowosh, o., Xu, L. 2018. Understanding the Impact of Production Slugging Behavior on Near-Wellbore Hydraulic Fracture and Formation Integrity. Presented at the SPE Interanational Conference and Exhibition on Formation Damage Control, Lafayette, Louisiana, USA, 7-9 February. SPE-189488-MS. 10.2118/189488-MS
Lupeau, A., Jolivet, G., Chazal, D., Fiore, M., Toussaint, C., Fournier, B., & Hollaender, F. 2014. October. Enhancements in Fraction Measurements and Flow Modeling for Multiphase Flowmeters. Presented at the SPE Annual Technical Conference and Exhibition, Amsterdam, The Netherlands, 27-29 October. SPE-170853-MS. 10.2118/170853-MS.
Nasri, A., Meshal A. Al-Amri, and Waleed A. Al-lsawi, Muhammad S. AI-Kadem. 2014. MPFM Accuracy Enhancements in a Scale Precipitation Environment: Lessons Learned and Guidelines.Presented at the International Petroleum Technology Conference, Kuala Lumpur, Malaysia, 10-12 December4. IPTC-17980-MS. 10.2523/IPTC-17980-MS.
Potapenko, D., Williams, R., Desroches, J.. 2017. Securing Long Term Well Productivity of Horizontal Wells through Optimization of Post Fracturing Operations. Presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, 9-11 October. SPE-187104-MS. 10.2118/187104-MS.
Saad H., Ribeiro, L.F.C., Oliveira, M. 2017. Multiphase Flow Measurement: Advantages and Brazilian Regulation. Presented at the SPE Offshore Technology Conference Brasil, Rio de Janeiro, Brazil, 24-26 October. OTC-28076-MS. 10.4043/28076-MS.
Theuveny, B., Maizeret, P. D., Hopman, N., Perez, S. 2007. The identification of Condensate Banking with Multiphase Flowmeters — A Case Study. Presented at the SPE Middle East Oil and Gas Show and Conference, Manama, Kingdom of Bahrain, 11-14 March. SPE-105362-MS. 10.2118/105362-MS.
Theuveny, B.C, Mehdizadeh, P. 2002. Multiphase Flowmeters Application for Well and Fiscal Allocation. Presented at the SPE Western Regional/AAPG Pacific Section Joint Meeting, Anchorage, Alaska, USA, May 20th-22nd. ", SPE-76766-MS. 10.2118/76766-MS.
Theuveny, B., Pithon, J.F., Loicq, O.,, Ségéral, G., 2002. Worldwide field experience of mobile well testing services with multiphase fiowmeters. Presented at the ASME Engineering Technology Conference on Energy, Houston, TX, USA, 4-5 February. ETCE2002/PROD-29039, pp. 771-785. 10.1115/ETCE2002/PROD-29039.
Theuveny, B., Segeral, G. and Moksnes, P.O. 2001. Detection and Identification of Scales Using Dual Energy-Venturi Subsea or Topside Multiphase Flowmeters. Presented at the SPE Offshore Technology Conference, Houston, Texas, 30 April - 3 May. SPE-13152-MS. 10.4043/13152-MS.
Wang, Z. and Krupnick, A. A retrospective Review of Shale Gas Development in the United States, April 2013: RFF DP 13-12, accessed June 24th, 2019: https://www.ourenergypolicy.org/wp-content/uploads/2013/05/Wang-and-Krupnick-Origins-of-the-Boom.pdf