Page 133 - Geochemistry of Oil Field Waters

REFERENCES 121

Various proportions of each are common. The determination is complicated
by the fact that acetic acid will not completely spend itself on calcium and
magnesium carbonates. At a pH of 5-6, considerable free acetic acid is still
present in the solution and this necessitates a modification of the procedure.
In this case, it is necessary to have a representative sample, or to prepare a
sample of the original acid mixture used on the acid job. Take 10-15 ml of
the treating acid and 10-15 ml of the returned water through the same
procedure as outlined for HC1.
Again a plot is constructed, percent spent acid versus milliliters CDTA.
Plot the milliliters CDTA used by the formation water as 0% spent acid and
the milliliters CDTA used by the injected acid sample as 100% spent acid as
illustrated in Fig.3.13. Connect these points by a straight line. From the
curve, determine the percent spent acid in the sample of returned water.
Other acid mixtures are sometimes used in oil wells. The handling of these
are usually too complicated for a rapid field determination.

References

American Petroleum Institute, 1968. API Recommended Practice for Analysis of Oilfield
Waters. Subcommittee on Analysis of Oilfield Waters, API RP 45, 2nd ed., 49 pp.
Angino, E.E. and Billings, G.K., 1967. Atomic Absorption Spectrometry in Geology.
American Elsevier, New York, N.Y., 144 pp.
Ballinger, D.G., Booth, R.L., Midgett, M.R., Kroner, R.C., Kopp, J.F., Lichtenberg, J.J.,
Winter, J.A., Dressman, R.C., Eichelberger, J.W. and Longbottom, J.E., 1972. Hand-
book for Analytical Quality Control in Water and Wastewater Laboratories. National
Environmental Research Center, Cincinnati, Ohio, 107 pp.
Bogomolov, G.V., Kudelskii, A.V. and Kozlov, M.F., 1970. Ammonium as one of the
indications of oil-gas content. Dokl. Akad. Nauk S.S.S.R., 195:938-940 (in Russian).
Brooks, R.R., Presley, B.J. and Kaplan, I.R., 1967. APDC-MIBK extraction system for
the determination of trace elements in saline waters by atomic absorption spectro-
photometry. Talanta, 14:809-816.
Burriel-Marti, F. and Ramirez-Munoz, J., 1957. Flame Photometry. American Elsevier,
New York, N.Y., 531 pp.
Collins, A.G., 1962. Methods of analyzing oilfield waters: flame-spectrophotometric
determination of potassium, lithium, strontium, barium, and manganese. US. Bur.
Min. Rep. Invest., No. 6047, 18 pp.
Collins, A.G., 1964. Eh and pH of oilfield waters. Prod. Monthly, 29:ll-12.
Collins, A.G., 1965. Methods of analyzing oilfield waters: cesium and rubidium. U.S. Bur.
Min. Rep. Invest., No. 6641, 18 pp.
Collins, A.G., 1967. Emission spectrometric determination of barium, boron, iron,
manganese, and strontium in oilfield waters. Appl. Spectrosc., 21 :16-19.
Collins, A.G., 1969. Solubilities of some silicate minerals in saline waters. U.S. Off. Saline
Water Res. Dev. Progr. Rep., No. 472, 27 pp.
Collins, A.G., Castagno, J.L. and Marcy, V.M., 1969. Potentiometric determination of
ammonium in oilfield brines. Environ. Sci. Technol., 3:274-275.
Collins, A.G., Waters, C.J. and Pearson, C.A., 1964. Methods of analyzing oilfield waters:
selenium and tellurium. U.S. Bur. Min. Rep. Invest., No.6474, 19 pp.
Collins, A.G., Pearson, C., Attaway, D.H. and Ebrey, T.G., 1962. Methods of analyzing
oilfield waters metallics: copper, nickel, lead, iron, manganese, zinc, and cadmium.
US. Bur. Min. Rep. Invest., No. 6087, 24 pp.