An Outright Success in Oil and Gas Production Arise from Surface Facility Modification – Story of Ujung Pangkah Field

2021 ◽  
Author(s):  
Ameria Eviany ◽  
Ifani Ramadhani ◽  
Cio Mario ◽  
Anang Nugrahanto ◽  
Harris Pramana ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Critical Surface ◽  
Operating Pressure ◽  
Suction Pressure ◽  
Pressure System ◽  
Oil And Gas Production ◽  
Wellhead Pressure ◽  
Pressure Depletion ◽  
Gas Lift

Abstract The two most common challenges on the oil and gas production today are the flowing production under natural pressure depletion and the surface facility capacity limitation. Ujung Pangkah field is no exception regarding finding a method to overcome this problem. It compelled to embolden many strategies to ensure the continuity of oil and gas production. Production enhancement initiatives were delivered through both Subsurface and Surface sides. SAKA Energi Indonesia, as the operator of Pangkah PSC, proved that Surface Modification approach increased the oil and gas production. Historically, gas lift injection dependency in all production wells force a continuous operation of Gas Lift Compressor (GLC) unit to supply gas lift. However, GLC as a production backbone is no longer sustainable, it has reached its maximum limit and unable to fulfil the gas lift rate requirement for all wells. Furthermore, the changing flowing conditions – low gas feeding - from wells are relatable to most of the critical surface equipment. Considering all the challenges faced in Ujung Pangkah field, SAKA developed initiatives on MP Compressor and GLC configuration by performing compressors restaging. The equipment modifications started out with restaging the MP Compressor (MPC) that led to MP Separator operating pressure reduction – from 22 barg down to 16 barg. Pressure changes on MP Separator also directly affected the GLC system since it works on the same pipeline header. Technical assessment analysis for other corresponding equipment were performed to verify if each of the equipment's operating boundary could accommodate lower pressure at the facility. Compressor restaging has direct and indirect impacts. The direct impacts are decrease in suction pressure, increase in gas lift rates, and decrease in flowing of suction pressure due to the pressure at wellhead. The indirect impact is production gain from wells by lowering the wellhead pressure. Particularly in the pressure depletion case, this initiative could extend the lifetime of the wells. Production gain was quantified after compressor restaging and pressure system lower to 16 barg. The gain from this method was 3 MMscfd and ~400 BOPD.

Upstream and Midstream Compression Applications: Part 1—Applications

2012 ◽  
Author(s):  
Rainer Kurz ◽  
Klaus Brun
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Gas Injection ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Gas Compression ◽  
Gas Lift

The upstream and midstream sectors of the oil and gas business require compression for a number of distinctly different applications, such as transmission, storage, gas gathering, gas lift, gas export, gas injection, flash gas compression, and refrigeration. This paper explains the purpose of and requirements for these applications within the context of oil and gas production and the transport of natural gas to the consumer. Typical operating requirements for the gas compressors, and typical solutions to meet these requirements are introduced.

scholarly journals Gas lift optimization in the oil and gas production process: a review of production challenges and optimization strategies

2020 ◽  
Vol 1 (2) ◽  
pp. 61
Author(s):  
Ikenna Tobechukwu Okorocha ◽  
Chuka Emmanuel Chinwuko ◽  
Chika Edith Mgbemena ◽  
Chinedum Ogonna Mgbemena
Keyword(s):  
Production Process ◽  
Oil And Gas ◽  
Gas Injection ◽  
Injection Rate ◽  
Gas Production ◽  
Optimization Techniques ◽  
Oil Well ◽  
Oil And Gas Production ◽  
Artificial Lift ◽  
Gas Lift

Gas Lift operation involves the injection of compressed gas into a low producing or non-performing well to maximize oil production. The oil produced from a gas lift well is a function of the gas injection rate. The optimal gas injection rate is achieved by optimization. However, the gas lift, which is an artificial lift process, has some drawbacks such as the deterioration of the oil well, incorrect production metering, instability of the gas compressor, and over injection of gas. This paper discusses the various optimization techniques for the gas lift in the Oil and Gas production process. A systematic literature search was conducted on four databases, namely Google Scholar, Scopus, IEE Explore and DOAJ, to identify papers that focused on Gas lift optimizations. The materials for this review were collected primarily via database searches. The major challenges associated with gas lift were identified, and the different optimization strategies available in the literature reviewed. The strategies reviewed were found to be based on artificial intelligence (AI) and machine learning (ML). The implementation of any of the optimization strategies for the gas lift will enhance profitability, reduce operational cost, and extend the life of the wells.

Re-Engineering Existing Pipelines in Western Canada

2006 ◽  
Author(s):  
Michael F. Hallihan
Keyword(s):  
Oil And Gas ◽  
Flow Direction ◽  
Gas Production ◽  
Western Canada ◽  
Operating Pressure ◽  
Oil And Gas Production ◽  
Well Completion ◽  
Service Conditions ◽  
Pipeline Design ◽  
Common Situation

The pipeline infrastructure throughout Western Canada is extensive, with more than 350,000 km in Alberta alone. As the profitability of oil and gas production swings, so too does the utilization of the pipeline infrastructure. During the 1990’s, the economics of some oil and gas production was marginal and the associated pipelines were under utilized. In particular, upstream producers deactivated several under utilized pipelines. Deactivated lines were blocked in, others purged and isolated, while others were completely abandoned. The profitability of oil and gas production has improved steadily since 1999 and the industry has pursued the reactivation of many of these pipelines. In several cases, the diligence of the pipeline operator during economically tight periods was less than desirable with respect to both of these functions. Poor economics also impaired the development and preservation of good pipeline design and maintenance records. The retention of the existing records was further impaired by the numerous corporate divestments and acquisitions that occurred over the past fifteen years. The lack of good quality pipeline records has hampered efforts to reactivate many pipelines. Another feature of our economic environment is the production of alternate zones from an existing well that was previously uneconomic. These zones often produce fluids significantly different than the original well completion and may not be consistent with the design of the original pipeline. This requires re-engineering of the pipeline for the new service. The most common situation is changing from one substance to another, however, changing the maximum operating pressure, changing the design temperature or changing the flow direction may also be required. The objective of this paper is to describe some of the specific challenges in reactivating dormant pipelines and re-engineering pipelines for new service conditions. The focus of this paper will be with respect to pipelines built to CSA Z183, Z184 or Z662 standards and the Alberta Pipeline Regulation.

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