Corrosion Assessment of Different Production Casings and Material Selection in Sour Gas Wells

Zeng, Dezhi; Zhang, Naiyan; Wang, Feng; Chen, Rui; Li, Tianlei; Ren, Cheng; Hu, Jie; Shi, Tao

doi:10.2118/176488-ms

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition 2015

DOI: 10.2118/176488-ms

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Corrosion Assessment of Different Production Casings and Material Selection in Sour Gas Wells

Dezhi Zeng

Naiyan Zhang

Feng Wang

et al.

Abstract: In order to assess the applicability of three steel specimens (T95, 110SS-2Cr and 825 steel) in sour gas well, corrosion tests were conducted in a simulated gas field solution containing both 0.55MPa H 2 S and 0.75MPa CO 2 at 55°C-100°C for 72h in an autoclave. Then the corresponding corrosion products were analyzed and compared through EDS and SEM technologies. The stress corrosion cracking (SCC) behavior of three steel specimens had been tested using four point bending (FPB) technique and constant-load test.… Show more

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Cited by 2 publications

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BD Gas Field Near-HPHT and Critical Sour Development: A Journey to Maintain Well Integrity

Tian¹,

Yustendi²,

Jihong³

et al. 2018

IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition

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BD Gas Field is located in offshore in the Madura Strait, Indonesia, and has a total of four producing wells - one vertical (Well Y1) and three horizontal (Well Y2, Well Y3, and Well Y4) from an unmanned platform. Its reservoir was considered near HPHT and critical sour with 8,100 psi bottom hole pressure, 300°F bottom hole temperature, 5.5% CO2 and 5,000 ppm H2S. This paper highlights on the Company journey to maintain well integrity during well design phase, well construction phase, and production phase of BD Gas Field. During well design phase, material selection and design for 9-5/8 in. intermediate casing, 7 in. production casing, and 4-1/2 in. tubing were based on the expected life of the well and reservoir properties in accordance to the requirements of NACE. Cementing design for 7 in. production casing cement was tested and analyzed in the laboratory for 60 days in the HPHT chamber simulating reservoir properties. Top of cement was designed to the mud line to minimize wellhead growth. Completion design was monobore type and divided into lower, intermediate, and upper completion strings. All packers were V-0 (zero bubble) rating. Maintaining well integrity during well construction phase was challenging. Batch drilling and completion was applied, and at all times, the wells were required to be suspended with proper and adequate barriers. During drilling and well clean-up phase, inter-casing pressure management (i.e., annulus pressure, wellhead growth monitoring, bleed off program, etc.) was implemented to maintain the casing and tubing integrity. During production phase, routine wellhead growth measurement, constant monitoring and bleed off program were developed and communicated with related departments. Pressure control valves and alarm system were installed and tested to the annulus. In additional to the wellhead growth, transverse wellhead movement was observed in one of the wells especially during rough sea conditions. In order to reduce the tranverse wellhead movement which may induce more stress on the surface pipings and connections, it was planned to install under water shims in between the conductor pipe and platform jacket guide funnel. Some surface piping and platform modification were also considered because wellhead growth leads to limitations on gas production to prevent safety issues.

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BD Gas Field Near-HPHT and Critical Sour Development: A Journey to Maintain Well Integrity

Tian¹,

Yustendi²,

Jihong³

et al. 2018

IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition

View full text Add to dashboard Cite

show abstract

An Integrated Geomechanics and Corrosion Assessment Approach to Analyze Tubular Degradation in Brownfield X

Sajjad

Wirawan

Chandra

et al. 2020

SPE Asia Pacific Oil &Amp; Gas Conference and Exhibition

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Tubular engineering design is essential for production operation, especially in the mature oil and gas fields. The complex interaction among oil, natural gas, and water, complemented with wax, scale, inorganic compound, and deformation brings complexity in analyzing tubular integrity. This challenging problem will be more severe if the wells are located in offshore environment, therefore finding the cause of tubing deterioration is a challenging. Field X, which has been in production for 30 years, cannot avoid the possibility of tubular thinning and deformation. The degradation is slowly developed until severe alterations are observed on the tubing body. The current state of the wells is complicated since the deformation inhibits the fluid flow and increases the risk of wellbore collapse and complications during sidetracking, infill drilling, workover, and other production enhancement measures. The risks can be harmful in the long run if not mitigated properly. The current condition encourages us to conduct more comprehensive study on tubular degradation. It is to model the multiple degradation mechanisms, such as corrosion, scaling, and subsidence, under the flowing formation fluid. The model is then coupled with reservoir simulation in order to provide a better outlook on tubular degradation. We used multiple case studies with actual field data to identify the dominant mechanism on tubular degradation. The case study cover various reservoir and fluid characteristics and also operations problems to develop general equation and matrix for risk analysis and field development considerations. We present the degree of tubular degradation and its effect to overall field performance and economics. Current field practices do not encourage a thorough tubular assessment during early life of the wells, which create complex problem at later stage. The study indicates that a proper planning and preventive action should be performed gradually before tubular degradation becomes severe. The paper presents a field experience-based model and guideline matrix that is useful in developing new areas from the perspective of well and facilities integrity, so that the degradation-related issues could be recognized earlier.

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Corrosion Assessment of Different Production Casings and Material Selection in Sour Gas Wells

Cited by 2 publications

References 10 publications

BD Gas Field Near-HPHT and Critical Sour Development: A Journey to Maintain Well Integrity

BD Gas Field Near-HPHT and Critical Sour Development: A Journey to Maintain Well Integrity

An Integrated Geomechanics and Corrosion Assessment Approach to Analyze Tubular Degradation in Brownfield X

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