This Pawr was selected for presentation by an SPE Prwram Committee following review of information containad m an abstract submittad by the author(s). Contents of the paper, as presented, have not been retiewed by the =ety of Petroleum Eng,neers and are subject to correction by the author(s). The material, aa presented, does not necessarily reflect anỹ itlon of the Society of Petroleum Engmeera, Its o~cera, w members. Papers presented at SPE meetings are subject 10 pub~cafion mtiew by Editorial Committees of the Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for mmmetial Purpmaa without the~tten consent of the *lety of Petroleum Engineers is prohibited. Permission to reproduce In print is restnctad to an abstract of not more than 300 tis; hllustratlons may not be copied. The abslract must contain mnspicuous acknowledgment of Mere and by tiom the papr was presented. Write Librarian, SPE, PO. Sax 833836, Richardson, TX 75083-3836, U. S.A., fax Ot -972-952-9435. AbstractIn fluvially dominated delta plain reservoirs, such as the Wara formation in the Greater Burgan Field, characterizing a reservoir's flow properties accurately is essential in developing a sound reservoir model. This is easier said than done. Typically, lithofacies identified in cores are correlated to multiple log suite characteristics. These are then used to help define simulation flow properties in wells. In Greater Burgan, with over fif~years of production, much of the field development occurred before modem diagnostic logging tools became available. Therefore, direct correlation of core lithologies and corresponding lithofacies description to multilog character is not possible in the majority of wells.Relationships discovered between shale volume (V~H) ranges and effective porosity (~to permeability transforms allowed us to apply unique rock properties to flow units or "facies" de fried by the V~H-porosity ranges. These flow facies eliminated the difficult task of trying to predict changing lithologies and lithofacies in wells with limited log traces and no core.

The paper describes the use of the Analytic Hierarchy Process in the strategic planning for the development of a series of reservoirs in the same field. A department of the Kuwait Oil Company is responsible for the development of these reservoirs and needed to determine the best order in which to develop these assets. In order to do this it was necessary to make judgements regarding how well any development option met a set of strategic criteria. At the individual reservoir level, it was also necessary to judge which development option best met a set of criteria for the development of specific reservoirs. A decision hierarchy was developed that reflected the ordering of the criteria and the specific alternatives. Pair-wise comparisons of the various criteria were made in order to determine how well they satisfied the overall objective. These judgments were evaluated using a judgment matrix to determine weights for the criteria. These criteria were applied to decisions to be made at the next lower level in the hierarchy. In this way, the decisions, which were judged to best meet the overall objective, were given the highest priority. This influence cascaded down through the hierarchy to rank the development options. With this structure it was simple to substitute one overall objective for another to determine whether this would cause a change in decision policy. The sensitivity of the decision outcome was also evaluated for its sensitivity to the range of values of the input factors. Since there were thirty-five factors to evaluate, a statistical design approach was used to evaluate factor effects. It is shown that the planning factors, planning horizon and the demand scenario used for planning purposes were significant in all cases evaluated, and highlighted the importance of testing the assumptions, criteria and objectives in a strategic planning exercise. Introduction Uncertainties in Strategic Planning Strategic planning is necessary for the proper development and management of any oil producing asset. However, there are many sources of uncertainty in any planning exercise. Uncertainties in input parameters, such as economic factors and production potentials, lead to uncertainties in predicted results. There are well documented means of addressing these uncertainties. We do not often give cognizance to the uncertainties in our planning parameters themselves, however, or test our strategic plans given different strategic objectives. It is not always clear what is the appropriate objective for our strategic planning. The executives of publicly traded companies will say it is to maximize NPV (net present value), or a similar metric. However, even publicly traded companies are subject to demands that may not be congruent to maximizing NPV, health, safety and the environment objectives, community improvement, security of management tenure, employee job security, investor interests, and other objectives, all have their constituencies. A system that provides a conceptually consistent means of weighting the set of appropriate objectives for any development would allow the explicit incorporation of the potentially disparate objectives into the ranking of projects. In addition, if we are uncertain as to what is the proper strategic objective, or if the objective changes due to changing circumstances, it would be beneficial to have a system that allows easy substitution of objectives for reevaluation. We could then determine how robust is our plan.

Kuwait's oil and gas reservoirs shape one of the largest reservoir portfolios worldwide, meriting savvy and forward-looking reservoir management practices and workflows to maintain the country as a reliable supplier for many decades to come. Reservoir management can be defined as a body of principles, processes, and practices that collectively governs the way a field is managed. It is focused on the subsurface, but not exclusively. Reservoir management is a stewardship process that significantly impacts production performance, bookable reserves, estimated ultimate recovery (EUR), and capital expenditures (CapEx). Kuwait Oil Company (KOC) has set out to optimize and standardize its reservoir management practices at a corporate level (Capello et al. 2016). This journey is still in progress, and has several strategic objectives: a) standardize reservoir management practices across KOC assets; b) ensure the optimization of recovery factors and life of fields strategies for each reservoir enabling the simultaneous production of nearby, connected or stacked producing intervals, with different maturity levels; c) extend production plateaus in time for each KOC asset; and d) ensure the active participation in reservoir management activities of a skilled workforce. The ultimate aim is to apply industry best practices in managing the oil and gas fields in Kuwait. The initiative is called Reservoir Management Best Practices (RMBP), and comprises a two-fold effort: A Steering Committee composed of 10 managers is charged with the implementation of reservoir management best practices policies and guidelines across all KOC assets. It was essential that management endorsed the initiatives and assured buy-in from other managers, team leaders and seniors in all assets and support organizations within KOC. Six Process Implementation Projects (PIP) were tackled with key objectives and elements of RM. It is envisioned that these PIPs will impact and uplift the way all assets work, so technical staff participation and buy-in was paramount for a successful implementation. The approach taken by KOC merges technical emphasis and international best-in-class practices with change management and communication strategies to align efforts. Most importantly, this solidifies and builds commitment and a shared motivation to achieve common goals. This paper summarizes the main accomplishments of KOC's RMBP to date, which span from workflows and governance in data management, to automation of drilling proposals and analog databases for reservoirs. KOC estimates these new processes will reduce operating costs and increase capital efficiency, which in turn will increase profitability by up to 15%.

SPE meet1ngs are subJect to publicot1on rev1ew by Ed1tcrial Committees of the Society of Petroleum Eng1neers Electronic reproduction, d1slflbulion, or storage of any part of this paper fer commmc1al purposes w1thout the wfltten consent of the Soc1ety of Petroleum Engineers is prohibited. Permission Lo reproduce 1n print is restncted to an abstract of not mora than 300 words; illustrations may not be copied. The abstract must contain conspicuous aclmowledgmont of where and by whom the paper was presented. Write Librarian, SPE, P.O Box 833836, Richardson, TX 75083-3836, US A , fax 01-972-952-9435.Abstr,-,ct API gravity vs. Depth correlations were developed for the Greater Burgan Field. The results of this work dramatically changed the determination of fluid PVT properties for the field which were used in Build-up analysis, wellbore flow correlations, simulation model initialization and OOIP estimates. Past PVT studies based solely on fluid sample analyses failed to honor the heavy oil or tar near the oil-water contact. Additional API gravity Vs depth data available from core dat3, and initial production tests were incorporated into the analysis. As a result, new correlations were developed which recognized values down to 10° API near the original 0\VC. Previous correlations did not have oil gravity samples lower than 24° API gravity.

As reservoirs mature, producing more oil out of maturing reservoirs entails more water production. For maturing reservoirs, it is, therefore, essential for a successful water management process to be introduced – one that can handle substantial volumes of water produced and result in increased oil production. Water management was not a major concern for Kuwait Oil Company (KOC) in the past. Most of its crude oil production were from Greater Burgan and other oil fields which were producing mostly dry, easy crude with little water production. With the ageing of Kuwait's oil fields, KOC is now experiencing an increase in water production from its maturing reservoirs. This increase is caused by both planned development and field maturity. Water production impacts the economics of oil field exploitation in number of areas like production volume, corrosions, crude quality, disposal, separation and metering. The accurate prediction of future water production trends is one of the most challenging tasks for KOC. A holistic approach to water management requires working out optimized development plan, enhanced oil recovery requirements, improving sweep efficiency, assessment of future total water injection and disposal needs, and surface handling facility requirements for both oil and water. Focused multilevel surveillance program, real time data gathering, tracking of water front movement, use of analytical models are part of several techniques used for water injection monitoring techniques to improve water flood conformance in KOC reservoirs. KOC is currently working an integrated water management plan to improve the overall performance of its reservoirs and establish synergy between different assets to utilize all its resources optimally.