This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 157429, ’Optimization of Limited-Entry Matrix Acid Stimulations With Laboratory Testing and Treatment Pressure Matching’ by Mary S. Van Domelen, SPE, and Mohamad abd Hammoud, Maersk Oil Denmark; Gerard Glasbergen, SPE, Shell; and Noor Talib, SPE, Maersk Oil Qatar, prepared for the 2012 SPE International Production and Operations Conference and Exhibition, Doha, Qatar, 14-16 May. The paper has not been peer reviewed. In the Danish central graben, tight chalk reservoirs have been developed successfully through drilling, completion, and stimulation of long horizontal wells. These fields, developed since the early 1970s, are operated on behalf of a joint venture, the Dansk Undergrunds Consortium (DUC). One of the most successful technologies used in these fields is the controlled-acid-jetting (CAJ) technique. Lower Cretaceous Formation, Central Graben Fig. 1 shows the major producing fields of the DUC area. The Lower Cretaceous reservoir contains significant in-place oil volumes. Fig. 2 shows the thickness map of the Tuxen and Sola Lower Cretaceous formation in the central graben. This formation historically has posed a challenge to development because of its extremely low permeability; in addition, the formation is soft, highly heterogeneous, and has significant clay content in some areas. Thicker Lower Cretaceous reservoir sections in the Valdemar field have been propped-fracture stimulated successfully. Acid stimulation is preferred for the thinner sections; however, early attempts at matrix acid stimulation were very disappointing. Recently, the need to re-enter a well for maintenance allowed three zones to be selectively restimulated with improved execution techniques and a more appropriate acid formulation. Production increase following restimulation of this first well was very encouraging, and the lessons learned were applied to a second well. The Lower Cretaceous formation is characterized by a high content of insoluble residue (IR), consisting mainly of clay with subordinate amounts of quartz, rare pyrite, and organic material. Porosity correlations were developed from core data and by petrophysical evaluation of logs. The porosity varies considerably, but is generally remarkably high. While the primary variation in porosity was linked directly to the IR content of the facies, factors such as pore pressure and depth of burial/compaction also had an influence. On the basis of the formation core data, the Lower Cretaceous would not be considered a good candidate for matrix acid stimulation. It is well established, however, that low-permeability reservoirs can be economically produced by long, horizontal wellbores that effectively maximize reservoir contact.