Lessons Learned on Gulf of Mexico Gas Wells Drilled With OBM and Completed with Heavy Brine

2007 ◽  
Author(s):  
Jim McBee ◽  
Brian Alan Evans ◽  
Kevin Umbehr
Keyword(s):  
Gulf Of Mexico ◽  
Lessons Learned ◽  
Gas Wells

Chemical Deliquification of Unconventional Gas Wells

2014 ◽  
Author(s):  
K.. Francis-LaCroix ◽  
D.. Seetaram
Keyword(s):  
Natural Gas ◽  
Best Practice ◽  
Oil And Gas ◽  
Large Deviation ◽  
Cost Effective ◽  
Gas Production ◽  
Lessons Learned ◽  
Offshore Platforms ◽  
Gas Wells ◽  
Current Production

Abstract Trinidad and Tobago offshore platforms have been producing oil and natural gas for over a century. Current production of over 1500 Bcf of natural gas per year (Administration, 2013) is due to extensive reserves in oil and gas. More than eighteen of these wells are high-producing wells, producing in excess of 150 MMcf per day. Due to their large production rates, these wells utilize unconventionally large tubulars 5- and 7-in. Furthermore, as is inherent with producing gas, there are many challenges with the production. One major challenge occurs when wells become liquid loaded. As gas wells age, they produce more liquids, namely brine and condensate. Depending on flow conditions, the produced liquids can accumulate and induce a hydrostatic head pressure that is too high to be overcome by the flowing gas rates. Applying surfactants that generate foam can facilitate the unloading of these wells and restore gas production. Although the foaming process is very cost effective, its application to high-producing gas wells in Trinidad has always been problematic for the following reasons: Some of these producers are horizontal wells, or wells with large deviation angles.They were completed without pre-installed capillary strings.They are completed with large tubing diameters (5.75 in., 7 in.). Recognizing that the above three factors posed challenges to successful foam applications, major emphasis and research was directed toward this endeavor to realize the buried revenue, i.e., the recovery of the well's potential to produce natural gas. This research can also lead to the application of learnings from the first success to develop treatment for additional wells, which translates to a revenue boost to the client and the Trinidad economy. Successful treatments can also be used as correlations to establish an industry best practice for the treatment of similarly completed wells. This paper will highlight the successes realized from the treatment of three wells. It will also highlight the anomalies encountered during the treatment process, as well as the lessons learned from this treatment.

Openhole Multistage Completion Evaluation Incorporating Deployment of Downhole Shut-in Tool Application in Sour Carbonate Gas Wells, Field Application

2021 ◽  
Author(s):  
Mauricio Espinosa ◽  
Jairo Leal ◽  
Ron Zbitowsky ◽  
Eduardo Pacheco
Keyword(s):  
Gas Flow ◽  
Operational Risk ◽  
Tool Design ◽  
Lessons Learned ◽  
Differential Pressure ◽  
Gas Wells ◽  
Flow Area ◽  
Gas Well ◽  
Heterogeneous Rocks ◽  
The Impact

Abstract This paper highlights the first successful application of a field deployment of a high-temperature (HT) downhole shut-in tool (DHSIT) in multistage fracturing completions (MSF) producing retrograde gas condensate and from sour carbonate reservoirs. Many gas operators and service providers have made various attempts in the past to evaluate the long-term benefit of MSF completions while deploying DHSIT devices but have achieved only limited success (Ref. 1 and 2). During such deployments, many challenges and difficulties were faced in the attempt to deploy and retrieve those tools as well as to complete sound data interpretation to successfully identify both reservoir, stimulation, and downhole productivity parameters, and especially when having a combination of both heterogeneous rocks having retrograde gas pressure-volume-temperature (PVT) complexities. Therefore, a robust design of a DHSIT was needed to accurately shut-in the well, hold differential pressure, capture downhole pressure transient data, and thereby identify acid fracture design/conductivity, evaluate total KH, reduce wellbore storage effects, properly evaluate transient pressure effects, and then obtain a better understanding of frac geometry, reservoir parameters, and geologic uncertainties. Several aspects were taken into consideration for overcoming those challenges when preparing the DHSIT tool design including but not limited to proper metallurgy selection, enough gas flow area, impact on well drawdown, tool differential pressure, proper elastomer selection, shut-in time programming, internal completion diameter, and battery operation life and temperature. This paper is based on the first successful deployment and retrieval of the DHSIT in a 4-½" MSF sour carbonate gas well. The trial proved that all design considerations were important and took into consideration all well parameters. This project confirmed that DHSIT devices can successfully withstand the challenges of operating in sour carbonate MSF gas wells as well as minimize operational risk. This successful trial demonstrates the value of utilizing the DHSIT, and confirms more tangible values for wellbore conductivity post stimulation. All this was achieved by the proper metallurgy selection, maximizing gas flow area, minimizing the impact on well drawdown, and reducing well shut-in time and deferred gas production. Proper battery selection and elastomer design also enabled the tool to be operated at temperatures as high as 350 °F. The case study includes the detailed analysis of deployment and retrieval lessons learned, and includes equalization procedures, which added to the complexity of the operation. The paper captures all engineering concepts, tool design, setting packer mechanism, deployment procedures, and tool equalization and retrieval along with data evaluation and interpretation. In addition to lessons learned based on the field trial, various recommendations will be presented to minimize operational risk, optimize shut-in time and maximize data quality and interpretation. Utilizing the lessons learned and the developed procedures presented in this paper will allow for the expansion of this technology to different gas well types and formations as well as standardize use to proper evaluate the value of future MSF completions and stimulation designs.

Lessons learned from data-limited evaluations of data-rich reef fish species in the Gulf of Mexico: implications for providing fisheries management advice for data-poor stocks

2019 ◽  
Vol 76 (9) ◽  
pp. 1624-1639 ◽  
Author(s):  
Skyler R. Sagarese ◽  
William J. Harford ◽  
John F. Walter ◽  
Meaghan D. Bryan ◽  
J. Jeffery Isely ◽  
...  
Keyword(s):  
Gulf Of Mexico ◽  
Reef Fish ◽  
Fish Species ◽  
Stock Assessment ◽  
Lessons Learned ◽  
Management Objectives ◽  
Trade Offs ◽  
Data Limitations ◽  
Management Procedures ◽  
Reef Fish Species

Specifying annual catch limits for artisanal fisheries, low economic value stocks, or bycatch species is problematic due to data limitations. Many empirical management procedures (MPs) have been developed that provide catch advice based on achieving a stable catch or a historical target (i.e., instead of maximum sustainable yield). However, a thorough comparison of derived yield streams between empirical MPs and stock assessment models has not been explored. We first evaluate trade-offs in conservation and yield metrics for data-limited approaches through management strategy evaluation (MSE) of seven data-rich reef fish species in the Gulf of Mexico. We then apply data-limited approaches for each species and compare how catch advice differs from current age-based assessment models. MSEs identified empirical MPs (e.g., using relative abundance) as a compromise between data requirements and the ability to consistently achieve management objectives (e.g., prevent overfishing). Catch advice differed greatly among data-limited approaches and current assessments, likely due to data inputs and assumptions. Adaptive MPs become clearly viable options that can achieve management objectives while incorporating auxiliary data beyond catch-only approaches.

Pushing the Limits in Offshore Mexico

2021 ◽  
Author(s):  
Hector Hugo Vizcarra Marin ◽  
Alex Ngan ◽  
Roberto Pineda ◽  
Juan Carlos Gomez ◽  
Jose Antonio Becerra
Keyword(s):  
Gulf Of Mexico ◽  
Real Time ◽  
Lessons Learned ◽  
Clear Understanding ◽  
Directional Drilling ◽  
Case Histories ◽  
Control Plan ◽  
Drilling Performance ◽  
Drilling Parameters ◽  
Drilling Engineering

Abstract Given the increased demands on the production of hydrocarbons and cost-effectiveness for the Operator's development wells, the industry is challenged to continually explore new technology and methodology to improve drilling performance and operational efficiency. In this paper, two recent case histories showcase the technology, drilling engineering, and real-time optimization that resulted in record drilling times. The wells are located on shallow water in the Gulf of Mexico, with numerous drilling challenges, which typically resulted in significant Non-Productive Time (NPT). Through close collaboration with the Operator, early planning with a clear understanding of offset wells challenges, well plan that minimize drilling in the Upper Cretaceous "Brecha" Formation were formulated. The well plan was also designed to reduce the risk of stuck pipe while meeting the requirements to penetrate the geological targets laterally to increase the area of contact in the reservoir section. This project encapsulates the successful application of the latest Push-the-Bit Rotary Steerable System (RSS) with borehole enlargement technology through a proven drilling engineering process to optimize the drilling bottomhole assembly, bit selection, drilling parameters, and real-time monitoring & optimization The records drilling times in the two case histories can be replicated and further improved. A list of lessons learned and recommendations for the future wells are discussed. These include the well trajectory planning, directional drilling BHA optimization, directional control plan, drilling parameters to optimize hole cleaning, and downhole shocks & vibrations management during drilling and underreaming operation to increase the drilling performance ultimately. Also, it includes a proposed drilling blueprint to continually push the limit of incremental drilling performance through the use of RSS with hydraulics drilling reamers through the Jurassic-age formations in shallow waters, Gulf of Mexico.

Advantages of Multistage Frac Completion in Vertical Depleted Gas Wells and Lessons Learned

2019 ◽  
Author(s):  
Ernest Sayapov ◽  
Alvaro Javier Nunez ◽  
Masoud Al Salmi ◽  
Ibrahim Al Farei ◽  
Hamdan Gheilani ◽  
...  
Keyword(s):  
Lessons Learned ◽  
Gas Wells

COMBINING MODELING WITH RESPONSE IN POTENTIAL DEEP WELL BLOWOUT: LESSONS LEARNED FROM THUNDER HORSE1

2005 ◽  
Vol 2005 (1) ◽  
pp. 719-723 ◽  
Author(s):  
CJ Beegle-Krause ◽  
Walton (Tad) Lynch
Keyword(s):  
Missing Data ◽  
Natural Gas ◽  
Gulf Of Mexico ◽  
Oil And Gas ◽  
Health And Safety ◽  
Lessons Learned ◽  
Safety Issues ◽  
Deep Well ◽  
The Subject ◽  
Health And Safety Issues

ABSTRACT In May of 2003 a drilling riser break at a BP development well in 6015 feet (1875 m) of water in the Gulf of Mexico initiated a dialog between BP responders and NOAA/HAZMAT modelers about the potential consequences of a deep well blowout. Human health and safety issues were the key concern for BP responders, particularly those planning potential on water operations. Where might the gas surface? Would the natural gas (propane and methane) at the water's surface pose an explosion or asphyxiation hazard? Was there a potential for the gas bubbles to sink any of the response vessels? These discussions did not have as cut-and-dry answers as either BP or NOAA would have preferred. During the planning for BP's attempt to bring the well back into operation, the General NOAA Oil Modeling Environment (GNOME) with the Clarkson Deep Oil and Gas model (CDOG, Zheng et al 2003, Chen and Yapa 2003 and Yapa and Cheng 2004) were run. The data required for modeling a deep spill is more extensive then for a surface oil trajectory and was the subject of much discussion between BP responders and NOAA/HAZMAT. As a result, NOAA/HAZMAT created a data summary request sheet (Appendix 1) to guide the BP responders in what data was needed, and provided a point of discussion for implications of missing data.

scholarly journals Current and Proposed Efforts to Resolve HSPD-5 and NCP Authorities (NIC and PFO)

2021 ◽  
Vol 2021 (1) ◽  
Author(s):  
LCDR John LaMorte ◽  
LT Rebecca Brooks
Keyword(s):  
Gulf Of Mexico ◽  
Oil Spill ◽  
National Guard ◽  
Lessons Learned ◽  
Coast Guard ◽  
Oil Well ◽  
Environmental Disasters ◽  
Oil Spill Response ◽  
Oil Rig ◽  
Exercise And Training

ABSTRACT During the evening of 20 April, 2010 U.S. Coast Guard District Eight Command Center watch standers received a report of an explosion aboard the Deepwater Horizon (DWH), an oil rig working on the Macondo oil well approximately 42 miles Southeast of Venice, LA (OSC Report, 2011). The explosion on board the DWH and resulting fires eventually destroyed the oil rig and caused it to sink into the Gulf of Mexico. Eleven crewmembers lost their lives in the tragic events that unfolded that night, and one of the nation's largest environmental disasters would soon follow. Estimates of the oil discharged from the Macondo oil well were between 12,000 and 25,000 barrels per day, and the response involved approximately 47,000 oil spill response personnel, 6,870 vessels, approximately 4.12 million feet of boom, and 17,500 National Guard personnel, five states (OSC Report, 2011). The massive oil spill lasted 87 days and estimates suggest that more than 200 million gallons of oil was discharged into the Gulf of Mexico, which stands as the largest oil spill event in U.S. history. From these massive response operations came important lessons learned for SONS event planning, preparedness, and response, as it became apparent during DWH response operations that oil spill response governance and doctrine was not well understood across the whole-of-government. This issue was well documented in the National Incident Commander's report and several recommendations were identified to address this issue. This paper will explore the steps taken within the U.S. Coast Guard's (USCG) SONS Exercise and Training Program to promote a better understanding of oil spill response governance and doctrine among Cabinet-level senior leadership and the interagency representatives that will ultimately be involved when the next SONS event happens.

scholarly journals Summary of Findings and Research Recommendations from the Gulf of Mexico Research Initiative

Oceanography ◽  
2021 ◽  
Vol 34 (1) ◽  
pp. 228-239
Author(s):  
Charles Wilson ◽  
◽  
Michael Feldman ◽  
Michael Carron ◽  
Nilde Dannreuther ◽  
...  
Keyword(s):  
Gulf Of Mexico ◽  
Oil Spill ◽  
Scientific Work ◽  
Lessons Learned ◽  
Future Research ◽  
Research Fields ◽  
Research Initiative ◽  
Response Measures ◽  
Oil Spill Response ◽  
High Level

Following the Deepwater Horizon explosion and oil spill in 2010, the Gulf of Mexico Research Initiative (GoMRI) was established to improve society’s ability to understand, respond to, and mitigate the impacts of petroleum pollution and related stressors of the marine and coastal ecosystems. This article provides a high-level overview of the major outcomes of the scientific work undertaken by GoMRI. This initiative contributed to significant knowledge advances across the physical, chemical, geological, and biological oceanographic research fields, as well as in related technology, socioeconomics, human health, and oil spill response measures. For each of these fields, this paper outlines key advances and discoveries made by GoMRI scientists (along with a few surprises), synthesizing their efforts in order to highlight lessons learned, future research needs, remaining gaps, and suggestions for the next generation of scientists.

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