Testing, Evaluation and Selection of CRAs
Evaluations of corrosion, pitting, sulfide stress cracking (SSC) and stress corrosion cracking (SCC) on 13Cr, Super 13Cr and 15Cr alloys in simulated oilfield environments. The experimental techniques employed were electrochemical critical pitting temperature (CPT) tests for CPT measurements, autoclave exposure (ACE) tests for corrosion, pitting, SSC and SCC evaluations and slow strain rate (SSR) tests for SSC and SCC evaluations.

Evaluation of some SS and Ni alloys in Acidizing Environments
The present study involved the evaluation of selected stainless and nickel base alloys in the following acidizing media: (1) 15 percent HCl, (2) 28 percent HCl, (3) 12 percent formic acid and (4) 13 percent HCl/2 percent HF. Tests were conducted both with H2S and with CO2 at 200 F and 400 F. Two different inhibitors were used in each acidizing media.

SCC Resistance of Alloy 825
Slow Strain Rate (SSR) tests were conducted to evaluate Alloy 825 for stress corrosion cracking resistance in an H2S/Brine environment at elevated temperatures.

Evaluation of CRAs for determining resistance to Corrosion & Cracking
Presented herein are the results of the Task 2 Corrosion Resistant Alloy (CRA) Evaluation. These tests were conducted to determine the corrosion and stress corrosion cracking behavior of selected high alloy materials under conditions simulating those found in the Thamama gas.

Material Selection for an Injection Well
The use of corrosion resistant alloy (CRA) tubulars for on injection well offers a method of providing (1) long term protection from corrosion and (2) maximum efficiency of flow. The use of these materials as downhole tubulars has only recently been attempted. Without extensive field experience on which to base materials selection decisions, expected performance has been based on evaluations conducted in the laboratory with simulated field environments. In these tests, the effects of corrosive species such as CO2, H2S, O2, brine and acids are quantified. Performance in terms of pitting, crevice and general weight loss corrosion behavior and stress corrosion cracking behavior must be determined.

Material Recommendations for Production of Wellhead and Christmas Tree Components
Presented herein is the review of material requirements a production well. This review includes evaluation of guidelines for wellhead and Christmas tree components which will be in contact with produced fluids under the following conditions: Partial Pressure CO2: 2.30 bar maximum; Partial Pressure H2S: 0.015 bar maximum; Water: 0-60 vol. Percent; Chlorides in Water: 2 wt. Percent; Reservoir Temperature: 94 C

Erosion Corrosion Evaluation of Cu-Ni Products
Flow loop tests were conducted to evaluated the erosion-corrosion resistance of cupro-nickel heat exchanger tubes. 95-5 and CA 122 tubes were subjected to 10, 15 and 22.5 ft/sec flow rates in 45 F refreshed tap water for three, six and nine month periods, then returned to a separate contractor for evaluation.