Pops I think the telling comment in this article is
But drillers haven't been able to get the Monterey Shale to produce oil at high rates. Brackett suggests that there are a few characteristics of the geology that could make the field more difficult to develop. There are lots of natural faults in the rock, which means drillers can't easily control the flow of oil through faults they create. Also, the rock is not under enormous pressure, so there is less force pushing the oil to the surface. And the oil may be relatively thick and sticky, which slows its flow.
Basically it isn’t analogous to other liquid rich shales such as the EagleFord which tends to be free of natural fractures and is overpressured. Most importantly my understanding is that the oil in the Monterey tends to be quite heavy (9 to 11 API) with surface temperature viscosities up to 10,000 cp. In comparison EagleFord oil has API in the mid-thirties and higher with viscosities in the tens of centipoise range.
To put that in context if you look at normal recovery factors for heavy oils from conventional reservoirs with similar rheology to the Monterey oil you are generally thinking of primary recovery from cold flow of not much more than 10%. In contrast light oil pools can see recovery factors in the 40% to 50% range, all other things being equal.