BACKGROUND: Universal contraceptive access is one of the key strategies for achieving sustainable developments in any country. Yet, uptake has remained low in most developing nations like Nigeria. The reasons for low use must be contextually understood to aid effective contraceptive programming. This study assessed contraceptive use and its determinants among reproductive aged women in Ejigbo, Osun State, Nigeria.METHOD: A quantitative study involving 405 participants which were recruited using multi-stage sampling method was carried out. Data were collected using pretested semi-structured, intervieweradministered questionnaire. Chi-Square test and binary logistic regression analysis were used for inferential statistics.RESULTS: The mean age of the respondents was 28±6. The majority (92.8%) of the respondents were aware of family planning, 68.9% of them possessed good knowledge but only 53% of them demonstrated favorable contraceptive attitude. Less than half (33.0%) of those who had heard about contraception were current users of modern methods. Injectables (45.0%) and male condoms (30.0%) were the most prevalent contraceptive methods among the respondents. The main determinants of contraceptive uptake were respondents’ educational status (AOR=0.525, 95%CI=0.284-0.972), contraceptive knowledge (OR=0.512, 95%CI=1.242-1.968) and attitude (OR=0.512, 95%CI=1.242- 1.968). Fear of perceived side effects (45.2%), low pregnancy risk perception (35.7%) and spousal refusal (12.5%) were the main reasons for non-contraceptive use among non-users.CONCLUSION: Contraceptive demand in the study population was low in spite of high awareness level. There is a need to increase contraceptive literacy in the study population and make the services more acceptable to rural dwellers so as to meet the SDG-3 target in Nigeria.

This paper reviews and shares lessons on the critical role of subsurface pressure data in the successful management of Agbami Field. Agbami is a Chevron operated deepwater asset located in 4,800 ft of water with a combination of water and gas injection development strategy. Production commenced in 2008 and has remained plateau at over 240 MBOPD. The field hosts intelligent well completions with capability of real time pressure data acquisition. In addition to this suite of pressure data from downhole gauges, wireline and LWD tools have been deployed to acquire valuable pressure data in the field. Several applications of reservoir pressure data in Agbami Field are shared in this paper. First, pressure data was used in establishing connectivity between a water injector and an oil producer in a rather poor seismic amplitude area. This led to significant savings from drilling another injector to support the 20,000 BOPD producer. Second, a reservoir originally interpreted as "virgin", which was later found to be depleted is described. This reservoir re-characterization resulted in over 20% increase in oil recovery. In another case, oil-water contact in a major reservoir was estimated using wireline pressure data, resulting in the booking of additional proved volumes. One key lesson is to always integrate pressure data with other data in the field. This integration often improves the asset team's understanding of the reservoir. A best practice is to ensure that all pressure data is quality checked before use to avoid erroneous interpretation. The availability of subsurface pressure data from different tools, at different gauge depths and at different times, poses a common challenge: RM practitioners who utilize these data need to ensure proper correction is done before field application.

In the buildup to the drilling campaign in Agbami, the field encountered disruption in its gas injection capability due to hydrate formation in one of the gas injection manifolds. In addition to this operational challenge was a delay in the arrival of the rig. The impact of these two major issues was higher depletion in reservoir pressures in the field than originally planned, with the attendant narrow drilling margin. This narrow drilling margin posed a significant challenge to the success of the drilling campaign. A multidisciplinary team comprising of Reservoir Engineers, Geologists, Drilling and Completion Engineers collaborated to assess the potential impact of these two issues on forthcoming drilling campaign. The team found out that the shallow reservoirs of the field were most impacted. The team then evaluated multiple options for addressing the foreseeable pressure depletion with its attendant drilling margin challenge. Leveraging the stream of downhole surveillance data from the intelligent completions in the field, reservoir simulation model was used to assess the optimal production and injection rates for the reservoirs, in addition to the priority given to the limited available gas and water for injection into the identified reservoirs that will boost pressure adequately prior to commencement of the drilling campaign. Furthermore, rig schedule optimization was carried out to align the well drill dates to those from the reservoir simulation. This joint effort resulted in improved reservoir pressures in the shallow reservoirs that enabled safe drilling margin during the successful drilling campaign.

Reservoir X01 and X02 are among the biggest reservoirs in AA field located in shallow waters offshore Nigeria. Production started from both reservoirs in 1965. By year 2001, the reservoir pressure in both X01 and X02 had each depleted by about 45% from their initial pressure. Furthermore, the reservoirs were observed to exhibit multiple pressure regions and fluid contacts at dynamic condition resulting from stratigraphic variation and differential production and injection across the reservoirs. Water injection commenced in 2002 into both reservoirs through peripheral waterflooding. It was observed that only the eastern regions of the reservoirs were benefitting from the water injection. By year 2011, reservoir pressure and production from the western region of both reservoirs had depleted significantly; several wells quit production while others had their production rate reduced. Utilizing historical pressure data, production data and other reservoir information, dynamic simulation was constructed to assess the impact of drilling two water injectors, Inj-03i and Inj-05i, in the western areas of reservoirs X01 and X02 respectively. The injectors were needed to provide pressure support as well as to improve sweep efficiency. In October 2011, Inj-03i and Inj-05i commenced water injection into the western region of X01 and X02 reservoirs respectively. By February 2013, reservoir pressure in the western area of X01 reservoir had risen to 1700 psi, from its pre-water injection value of 1000 psi. Similarly in the western area of X02 pressure increase of 300 was observed post water injection in Inj-05i. Three wells that had earlier quit production in X01 reservoir were restored back to production while two shut-in wells in X02 reservoir were also restored to production. A total incremental production of 5,500 BOPD was attributed to the improved performance in the two reservoirs as a result of the drilling of the two water injectors. Recent flowing and static pressure data were valuable in designing production restoration jobs.