Continuous Injection of Hydrate Inhibitor in Gas Lift Gas to Mitigate Downtime Due to Downhole Annular Plugging
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1 32 nd Gas-Lift Workshop The Hague, The Netherlands February 2-6, 2009 Continuous Injection of Hydrate Inhibitor in Gas Lift Gas to Mitigate Downtime Due to Downhole Annular Plugging John R. Cliver and Chris M. Robinson* ExxonMobil Production Company** * C. Robinson currently with Chevron Texaco ** ExxonMobil Production Company is a division of Exxon Mobil Corporation (ExxonMobil). As used in this material, the term ExxonMobil may refer to Exxon Mobil Corporation, one of its division, or a subsidiary or affiliated company. The shorter term is used here only for convenience and simplicity. This presentation is the property of the author(s) and his/her/their company(ies). It may not be used for any purpose other than viewing by Workshop attendees without the expressed written permission of the author(s).
2 Outline Downhole Annular Plugging Downtime Defining the Problem Modeling Approach Solution Evaluation Implementation and Results 2009 Gas-Lift Workshop 2
3 Downhole Annular Plugging Downtime Gas Lift Gas Well # Casing Pressure 1 IPO for unloading SCSSV GLM Mud Line Vacuum Insulated Tubing Casing Pressure (PSIG) Gas Lift Injection Rate (MMCFD) 1 Orifice Valve GLM BHP CIM X XN Casing Pressures Time (Days) Gas Lift Rates Pressure and Gas Lift Rates for a Problem Well 0 Reservoir / Perfs Typical Well Configuration Similar trends seen in 30% of the platform s producing wells 2009 Gas-Lift Workshop 3 3
4 Defining the Problem Sweet Produced Gas Sour Associated Gas Glycol Contactor & Depropanizer Gas from Production System (1100psi) Injection Gas Compressors Injection gas Coolers Problem Assumed to Stem from 1 of 2 Causes: To Gas Injection headers (2600 psi) 1. Hydrates forming due to lack of sweet gas dehydration 2. Asphaltenes asphaltene precipitation from sour gas 2009 Gas-Lift Workshop 4
5 Two Potential Mechanisms Theory Support for Theory Asphaltenes Solid organic material plugs inside of gas lift orifice Bleeding down pressure causes material to fall out of orifice Observed black hydrocarbon material on exterior of production tubing when pulled for workovers Problem did not go away when methanol pumped during gas lift delivery event Hydrates Pressure drop across valves causes temperature to drop into hydrate formation region Bleeding down casing pressure melts the hydrate plug Sweet gas lift gas not dehydrated before going to injection Problem wells contain vacuum insulated tubing (VIT), nonproblem wells generally did not Potential Solutions Replace gas lift valves Wash backside of tubing using xylene Heat gas before going downhole Pump hydrate inhibitor chemical into annulus with gas lift gas 2009 Gas-Lift Workshop 5
6 Vacuum Insulated Tubing 3.5 OD Inner Tubing 4.5 OD Outer Tubing Welded on ends, at connection Significantly reduces heat loss by limiting conduction and radiation Intended to prevent heat loss in the oceansubmersed portion of tubing Isolates heat transfer between hot, produced fluids and gas lift gas 2009 Gas-Lift Workshop 6
7 Hydrate Prediction Modeling Approach q in q out R 1 R 2 R 3 R 4 R 5 R 6 Gas Lift Mud Line T production T gas lift T ambient Casing Pressure Gas Lift Valves SCSSV GLM Vacuum Insulated Tubing 1. Heat Balance in Gas Lift Gas Stream to predict temperature profile GLM BHP CIM X XN 2. Thermodynamic Modeling of fluids to predict hydrate temperatures and pressures Reservoir / Perfs 2009 Gas-Lift Workshop 7
8 Modeling Output waterline Elevation [ft] seafloor T-gas lift T-ocean/ soil T-hydrates Temperature [ o F] 2009 Gas-Lift Workshop 8
9 Modeling Results Gas lift gas is more likely to form hydrates at lower injection rates waterline waterline Elevation [ft] seafloor T-gas lift T-ocean/ soil T-hydrates Elevation [ft] seafloor T-gas lift T-ocean/ soil T-hydrates Temperature [ o F] Gas lift temperature profile: 1.6 MMcfd injection Temperature [ o F] Gas lift temperature profile: 0.5 MMcfd injection 2009 Gas-Lift Workshop 9
10 Modeling Results Summary minimum gas lift gas temperature critical hydrate zone Temperature [ o F] Increasing 2600 psig, HYD 2400 psig, HYD 2200 psig, HYD 2000 psig, HYD 1800 psig, HYD Gas Lift Rate [MMcfd] Modeling indicates that hydrate formation is likely below 1.1 MMcfd 2009 Gas-Lift Workshop 10
11 Potential Solutions Evaluated Maintain gas lift rates above 1.1 MMcfd Install dehydration facilities for sweet produced gas Eliminate vacuum insulated tubing Eliminate the gas lift cooler upstream of gas lift injection headers Inject hydrate inhibitor when a plug develops Continuously inject hydrate inhibitor chemical into gas lift 2009 Gas-Lift Workshop 11
12 Potential Solution: Remove Gas Lift Gas Coolers waterline waterline Elevation [ft] seafloor T-gas lift T-ocean/ soil T-hydrates Elevation [ft] seafloor T-gas lift T-ocean/ soil T-hydrates Temperature [ o F] Temperature [ o F] With Coolers (current) Without Coolers Removal of injection gas coolers upstream of injection headers will not prevent hydrate formation 2009 Gas-Lift Workshop 12
13 Potential Solutions Evaluated Maintain gas lift rates above 1.1 MMcfd Install dehydration facilities for sweet produced gas Eliminate vacuum insulated tubing Eliminate the gas lift cooler upstream of gas lift injection headers Inject hydrate inhibitor when a plug develops Continuously inject hydrate inhibitor chemical into gas lift 2009 Gas-Lift Workshop 13
14 Implementation and Results Further thermodynamic modeling and evaluation showed Ethylene Glycol injection to be the most cost-effective hydrate inhibitor Currently injecting chemical continuously at low dosages (0.5 gal / day / well) 3000 Well # Well #1 6 Casing Pressure (PSIG) Gas Lift Injection Rate (MMCFD) Casing Pressure (PSIG) Gas Lift Injection Rate (MMCFD) Casing Pressures Time (Days) Gas Lift Rates Casing Pressures Time (Days) Gas Lift Rates 2009 Gas-Lift Workshop 14
15 Questions? Continuous Injection of Hydrate Inhibitor in Gas Lift Gas Mitigates Downtime due to Downhole Annular Plugging Acknowledgements Phil Carrigee Cliff Corbell James Cunningham Mike Johnson John Martin Joseph Pergler Bryan Pickett Bryan Wesley Lester Matthews 2009 Gas-Lift Workshop 15
16 Copyright Rights to this presentation are owned by the company(ies) and/or author(s) listed on the title page. By submitting this presentation to the Gas-Lift Workshop, they grant to the Workshop, the Artificial Lift Research and Development Council (ALRDC), and the American Society of Mechanical Engineers (ASME), rights to: Display the presentation at the Workshop. Place it on the web site, with access to the site to be as directed by the Workshop Steering Committee. Place it on a CD for distribution and/or sale as directed by the Workshop Steering Committee. Other uses of this presentation are prohibited without the expressed written permission of the company(ies) and/or author(s) who own it and the Workshop Steering Committee Gas-Lift Workshop 16
17 Disclaimer The following disclaimer shall be included as the last page of a Technical Presentation or Continuing Education Course. A similar disclaimer is included on the front page of the Gas-Lift Workshop Web Site. The Artificial Lift Research and Development Council and its officers and trustees, and the Gas-Lift Workshop Steering Committee members, and their supporting organizations and companies (here-inafter referred to as the Sponsoring Organizations), and the author(s) of this Technical Presentation or Continuing Education Training Course and their company(ies), provide this presentation and/or training material at the Gas-Lift Workshop "as is" without any warranty of any kind, express or implied, as to the accuracy of the information or the products or services referred to by any presenter (in so far as such warranties may be excluded under any relevant law) and these members and their companies will not be liable for unlawful actions and any losses or damage that may result from use of any presentation as a consequence of any inaccuracies in, or any omission from, the information which therein may be contained. The views, opinions, and conclusions expressed in these presentations and/or training materials are those of the author and not necessarily those of the Sponsoring Organizations. The author is solely responsible for the content of the materials. The Sponsoring Organizations cannot and do not warrant the accuracy of these documents beyond the source documents, although we do make every attempt to work from authoritative sources. The Sponsoring Organizations provide these presentations and/or training materials as a service. The Sponsoring Organizations make no representations or warranties, express or implied, with respect to the presentations and/or training materials, or any part thereof, including any warrantees of title, noninfringement of copyright or patent rights of others, merchantability, or fitness or suitability for any purpose Gas-Lift Workshop 17
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