Acid Corrosion Inhibitors - Are We Getting What We Need?

Smith, C.F.; Dollarhide, F.E.; Byth, Nancy J.

doi:10.2118/5644-pa

Cited by 57 publications

(19 citation statements)

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“…API grading is based on tensile strength and not metallurgy or chemistry. 7 3. The chemical composition of commercially available ZnBr2 varies from one manufacturer to another.…”

Section: Special Considerations For Laboratorymentioning

confidence: 99%

Solids-Free, High-Density Brines for Packer-Fluid Applications

Ezzat¹,

Augsburger²,

Tillis³

1988

Journal of Petroleum Technology

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High-density water-or oil-based muds are not stable suspensions. Laboratory corrosion data and field observations suggest that solids-free, inhibited high-density brines could be ideal packer fluids for deep, hot wells. Expensive washover and fishing operations required for recovery of tubing stuck in settled mud solids could be eliminated. 2. Fluids must not deteriorate packer elastomers. 6 3. Fluids must remain pumpable during the life of the well; i.e., no high gelation or solidification may develop over time. 3,4 4. Fluids must not cause corrosion (inside casing or outside tubing).5. The fluids must not damage the producing formation because they may contact these producing zones during completion or workover operations. 3Water-based drilling-mud organic additives degrade upon prolonged exposure to high temperatures and sometimes generate corrosive gases, such as CO 2 and H 2 S. 3-5 Bacterial activity could also break down organic materials and/or produce corrosive elements.Lignosulfonate solutions can react electrochemically at metal surfaces to form sulfides, even at moderate temperatures. 3,4 Properly formulated oil-based muds are nonconductive and should not cause corrosion. 4 In case of packer failure or leaks, however, produced oil or gas dissolves in oil mud and destroys the suspension properties, allowing the weighting material (barite) to settle on top of the packer and to cause stuck packer and tubing.

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“…API grading is based on tensile strength and not metallurgy or chemistry. 7 3. The chemical composition of commercially available ZnBr2 varies from one manufacturer to another.…”

Section: Special Considerations For Laboratorymentioning

confidence: 99%

Solids-Free, High-Density Brines for Packer-Fluid Applications

Ezzat¹,

Augsburger²,

Tillis³

1988

Journal of Petroleum Technology

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“…[116][117][118][119][120][121][122][123][124][125] Any potential incompatibilities between acid and formation solids or fluids must be identified before acidizing. Compatibility of both live and spent acid with the formation fluids should be tested.…”

Section: Acids and Additivesmentioning

confidence: 99%

Matrix Acidizing

McLeod

1984

Journal of Petroleum Technology

152

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Distinguished Author Series articles are general, descriptive representations that summarize the state of the art in an area of technology by describing recent developments for readers who are not specialists in the topics discussed. Written by individuals recognized as experts in the area, these articles provide key references to more definitive work and present specific details only to illustrate the technology. Purpose: to informthe general readership of recent advances in various areas of petroleum engineering. Introduction Many excellent and useful papers have been written on the subject of matrixacidizing. Included in this article is an extensive bibliography that should beuseful to the engineer in the design and execution of a matrix acidizing treatment in limestone or sandstone formations. The first matrix acidizing jobswere very successful in stimulating oil production in carbonates. However, mostof the recent attention to matrix acidizing concerns sandstones and the use ofvarious hydrofluoric acid systems. Matrix acidizing in carbonate formations still is beneficial in high-permeability, damaged formations (50 md or more). Damage can occur during drilling, completion or production of a well. Incarbonates with permeabilities less than 10 md, acid fracturing generally is used because much greater stimulation is obtained with long, acid-etched fractures in low-permeability reservoirs. Although the acid systems used insandstones and carbonates differ, the same practices apply to both. Well Performance (Need for Acidizing) Successful acidizing depends on the presence of damage and its location and intensity. The closer the damage is to the perforations, the more easily acidcan get to it. Compacted or crushed zone damage from perforating overbalancedcan be removed easily by acid, since only about 1/2 in. [1.3 cm] of damage mustbe removed directly around the perforation. Precipitates from previous acid treatments more than 1 ft [0.3 m] from the wellbore in sandstone or 5 ft [1.52m] in carbonate will be either impossible to reach with matrix acidizing or too expensive to treat. Deep solid plugging, will be corrected more effectively bycreating a conductive fracture through the damage either by sand fracturing oracid fracturing. Nonplugging damage (e.g., oil wetting) may be several feet deep around the wellbore, but reverse wetting surfactants can penetrate andreverse the formation to a water-wet condition at reasonable cost. Oil wetting damage usually is less severe than solid plugging damage, so correctivechemicals can reach the affected area easily. High-permeability formations (those with 100 md or more) seem to be dominated by either formation damage or tubing size flow restrictions. This is particularly true of gravel-packed offshore wells. When well flow is markedlyless than similar wells in the same reservoir, most of the drawdown probably isoccurring at the wellbore through a small zone of reduced permeability. Mostrecent gravel-pack-damage research has focused on gravel-packed tunnels andquality of the gravel in the tunnel. Current techniques have improved so muchin recent years that gravel-packed tunnels usually offer little flow resistance when perforating density is adequate. Nevertheless. reduced flow throughgravel-packed wells still occurs. Current research focuses onincompletely packed tunnels andformation-sand damage near the entrance to the tunnels. Torrest and Stein described gravel shifting in tunnels when the gravel pack is not packed tightly during placement. Damage to formation sand before gravelplacement will cause premature pressure outs resulting from viscous fluidsentering damaged or reduced permeability near the perforations. Because of highpressures, pumping may be halted before the gravel has concentrated adequately in the perforation tunnels. If the pumping stops too soon, the tunnels will befilled only partially with quality gravel. When the well is produced, formations and will enter the tunnels, bridging on the gravel inside the tunnel andpacking the partially void tunnel with formation sand, which is much lower inpermeability than the gravel. As the formation sand fills the tunnels. the pressure drop through the completion increases and the flow rate declines. JPT P. 2055^

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“…The glass beaker contained 100 mL of 20 wt.% aqueous MSA (one test was also performed with 7.5 wt.% HCl, see below). A volume of 100 mL test solution is a common industrial practice when performing corrosion tests . Moreover, the CR of 22Cr in MSA was low (see below) and saturation of the corrosion products in the test MSA solution was not achieved.…”

Section: Methodsmentioning

confidence: 99%

The corrosion resistance of 2205 duplex steel in non‐inhibited methanesulphonic acid at elevated temperature

Finšgar

Jackson

2015

Materials & Corrosion

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The corrosion behavior of 2205 duplex stainless steel in methanesulphonic acid (MSA) at elevated temperature was investigated. It was proposed that uninhibited MSA could be utilized in acidizing procedures in petroleum wells constructed of 22Cr steel. The MSA was suggested as a substitute for conventional acids such as HCl which require the use of corrosion inhibitors. Corrosion rates of 22Cr steel in MSA solution with or without 24.13 bar CO 2 at 150 8C after 6 h of immersion were lower than what is often required by the petroleum industry. In conditions of H 2 S-containing MSA, significantly higher corrosion rates were observed.

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Acid Corrosion Inhibitors - Are We Getting What We Need?

Cited by 57 publications

References 0 publications

Solids-Free, High-Density Brines for Packer-Fluid Applications

Solids-Free, High-Density Brines for Packer-Fluid Applications

Matrix Acidizing

The corrosion resistance of 2205 duplex steel in non‐inhibited methanesulphonic acid at elevated temperature

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