bluuebunny/crossref_metadata_2025_split huggingface dataset:
How to Make Injection More Effective and Get Production More Optimum - A Good Case From China
Authors: Ming Liu , Shengyun Zhan , Weige Yan , Shigang Ma , Ruichang Yan 
Published: June 2014

AbstractBZ25-1S oilfield is a large heavy oil reservoir with narrow and thin fluvial channels in Bohai bay developed by CNOOC and Chevron. Due to large well spacing (350-450m), it is difficult to characterize the connectivity between sand bodies and determine the response of oil production on water injection. The early field oil production and pressure declined at the rate of 4.4% per month and 0.6 MPa per month respectively because of insufficient natural energy. The results of water-oil displacement in cores indicate that there was no non-water production period and the recovery factor would not more than 5% when field water cut reaches 70%.Focusing on these main problems in the reservoir, comprehensive water injection and production optimization technology was applied based on study of detailed reservoir characteristics: 1) Combining research on geology and field outcrops and analysis of reservoir dynamic performance, we carried out detailed reservoir description of sand bodies and systematically analyzed the response of oil production on water injection for this type of reservoirs; 2) An innovative technology of production optimization has been developed. It takes the nature of offshore production technology into account, constantly adjusts water injection rate and controls water production amount so that water displacement efficiency improved; 3) An advanced surface water injection and production technology such as selective injection supporting the implementation of the production optimization techniques has been also developed.Field production data showed that 95.6% of the wells displayed positive responses to water injection in which led to stable reservoir pressure, slower production decline, and slightly water cut increase. The filed oil rate has been stabilized for about four years without water breakthrough in large scale and the overall recovery factor is expected to improve more than 5%.
The Impact of Layering on Production Predictions from Observed Production Signatures, Shushufindi Project, Ecuador
Authors: Corbett Chip , Lafournere Jean-Paul , Bolanos Jorge , Bolanos Maria Janeth , Frorup Mik , Marin Gustavo 
Published: June 2014

Abstract
The Shushufindi field (Fig. 1) was discovered in 1972 and is sparsely developed, with only 181 wells covering an area of approximately 400 km2. Recovered whole core from the well SSF-151D presents very thin streaks of quartz material, along with carbon and amber, which form vertical permeability barriers in the cored section, approximately one inch thick. Production profiles for many wells in the field present a very gradual increase in the water cut from an active edgewater drive aquifer and demonstrate a layered system. This implies that the vertical permeability barriers are areally extensive, and that they have a substantial impact on production predictions and development scenarios. The challenge for the subsurface team is to represent these thin barriers in a predictive simulation model.
A standard Kv:Kh ratio is insufficient to mimic the observed production response. A very fine-scale geomodel could be considered but is computationally expensive. Vertical transmissibility multipliers are useful in a simulation model, but experiments demonstrate that the lateral extent of the barriers is discontinuous. Diagnostic plots of the well water/oil ratio (WWOR) versus the cumulative liquid production (WLPT) can identify groups of wells with layered production profiles. This information provides a basis to infer the potential for a layered production response from existing well logs. To introduce such discontinuities, a series of randomly generated vertical baffles have been created which provide an improved simulation response in a relatively coarse simulation model.
Early water breakthrough, and excessive water production in some wells caused premature re-completions into other zones. This type of sub-surface modeling provides support for the introduction of intelligent completions to isolate specific layers as part of the development plan.
This paper presents the techniques implemented by the team, the results to date, and a prognosis for the future of the field.
Unveiling Reservoir Characteristics of a Vintage Field, Shushufindi Project, Ecuador
Authors: Lafournere Jean-Paul , Dutan Jorge , Naranjo Michelle , Bringer Florent , Suter Andreas , Vega Jorge , Bolaños Jorge 
Published: June 2014

Abstract
The Shushufindi field, located in the Oriente basin of Ecuador, has been producing since 1972. In December 2011, the field had approximately 150 wells, with a total production of 45,000 bopd. Field operations were then passed to the Consorcio Shushufindi (CSSFD) led by Schlumberger for a period of 15 years. Since then, 30 new wells and 26 workovers have been completed by Schlumberger Production Management (SPM) in the field, with a production of 60,000 bopd in May 2013.
A methodology with four successive distinct phases was created, aiming for a complete reservoir characterization over 18 months prior to delivering the five-year field development plan (FDP) in October 2013. Each petrophysical phase focused on providing a reliable basis for the first two years of operations, and regular updates to the static and dynamic models.
In conjunction with operations support, a comprehensive data acquisition plan was launched with advanced core analysis and special logs to support the advanced reservoir characterization. The deployment of technologies such as the Dielectric Scanner* multifrequency dielectric dispersion service, the combinable magnetic resonance tool, and the FMI* fullbore formation microimager, among others, was key in revealing the reservoir's true characteristics.
Advanced petrophysics delivered a description of the main reservoir heterogeneities and properties, along with a facies characterization tied to an advanced core analysis including capillary pressure and pore throat size measurements. From this, hydraulic flow units were established in a deterministic characterization over the waterflood pilot well patterns. Additionally, a quantitative evaluation of thin beds and low resistivity pay zones provides the potential for their incorporation in the original oil-in-place computation. These findings have contributed to a revision of the depositional concepts for the field.
The Conditions of Accumulation of Petroleum in the Earth
Authors: Day David T. 
Published: June 2014

In 1897 I published a proposed explanation for the variation in color andspecific gravity of Pennsylvania oils. A resume of this subject was alsopresented at the First International Petroleum Congress, in Paris, in 1990.Since that time much experimental work bearing upon this explanation has beencarried on by me, in the United States Geological Survey, and under mydirection, by Dr. J. Elliott Gilpin, Marshall P. Cram, and O. E. Bransky, atthe Johns Hopkins University. The experimental results thus accumulated seem tothrow considerable additional light upon the variations in color and specificgravity of petroleum, as found in different parts of the world, and also uponthe variations in chemical composition. Therefore, it seems as if a summary ofthe evidence thus obtained might be of value to those members of the Institutewho are interested in the examination of oil- fields. The summary is herepresented for that purpose.
The phenomenon has often been observed in many oil-fields that oils of different color, specific gravity, and chemical composition may be foundwithin short distances of each other. A conspicuous example of this is the occurrence at Jennings, Welsh, and Anse la Butte, La., of petroleum chemicallysomewhat similar to Russian petroleum; that is, characterized by the presenceof naphthenes. Another characteristic is the presence of considerablepercentages of asphaltic compounds, sufficient in quantity to disguise the presence of' solid paraffin wax, and perhaps also to render that paraffin waxmore soluble in the oil than it would be were not these asphaltic compoundspresent. At Belle Isle, La., only 40 miles from Anse la Butte, petroleum isfound unusually light in color, about that of sauterne wine. This petroleum ispractically free from sulphur, very much lighter in specific gravity than theother oils, free from asphalt, and shows abundantly the presence of paraffinwax in solution. At first glance the oils seem to be entirely different, butchemical examination shows them to be as closely related to Russian oils as arethose from Texas, and markedly different from the oils of theparaffin-hydrocarbon series found in Pennsylvania.
Other instances are noted of similar variations in oils within short distances, especially in Mexico, as well as in California, Wyoming, Oklahoma, Texas, andelsewhere. The oils usually, however, contain some characteristics in common, which would indicate that one oil has been derived from the other. Inendeavoring to express such a genetic relationship, it has been supposed thatthe dark oils have been derived from the lighter ones by evaporation andoxidation.
AIME 041–24
Present Conditions in the California Oil-Fields
Authors: Requa Mark L. 
Published: June 2014

During the two past years California has developed a new and importantoil-field: I refer to Midway. This field produced the famous Lake View gusher, which is credited with a total production in excess of 8,000,000 barrels. Fortunately for the oil industry of the State, this well is not a thing of the past, and nothing save agreat crater-like opening marks its location. The pipe is entirely work away and gone; and it is a matter of serious doubt ifthere can be anything done that will cause the well to produce again. Fortunately, also, there have been no other wells inthat field or elsewhere throughout the State that in any way compared with the Lake View. Midway is noted for large wells, of from 500 to 2,000 barrels production; but the decline is rapid, and a few months serve to bring the output down to a fewhundred barrels.
In the oil-territory heretofore blocked out as proved and probable, therehave been, during the year, many changes. Some areas which were expected to be fairly productive have apparently failed;others, more strictly ?wild-cat?, have come in; while in some of the older fields there are properties which are beginning toshow evident signs of exhaustion. The total area of proved territory will therefore probably suffer but small increase, when balances are struck off. The increase of new area has come from extensions of the Midway field, the development of a fieldin Lost Hills and Belridge, and extensions of the Fullerton-Whittier field in southern California. In these laterdevelopments, down to date, the fresh area absolutely proved is not much in excess of 3,000 acres. Recent developments in Coalingaindicate the possible extension of that field to the south, but at great depth. Coalinga is still the most northerly field ofany consequence in the State. The Kettleman Hills have hitherto brought in nothing, although a depth exceeding 3,500 ft.has been reached. Much of the territory proved within the year is extremely deep and expensive to develop and operate.
This, however, is not true as regards a narrow strip in the Lost Hills andthe proved tract ill the Belridge fields, located respectively 26 and 13 miles NW. and N. of McKittrick. In these fieldsit is claimed that at depths varying from 600 to 1,200 ft., 200- to 500-barrel wells are the rule, producing oil of 23"gravity and higher. So far as can be foreseen at the moment, this territory is the most disturbing factor in the State, asregards the future price of oil. It is yet too early to predict with accuracy the possibilities of these two fields, andespecially of the Belridge territory, but that there is oil underlying the locality at comparatively shallow depths, admits ofno question. Thickness of sand, saturation, area proved, and sundry other factors necessary to be determined before anyestimate can be made, are as yet not obtainable.
AIME 042–61
Possible Oil and Gas Fields in the Cretaceous Beds of Alabama
Authors: Hager Dorsey 
Published: June 2014

The possibility of oil and gas production in Alabama has been littleconsidered as yet. Gas and some oil have been found in northwestern Alabama, near Birmingham, in the Pennsylvanian beds, but the oil and gas possibilitiesin the Cretaceous beds are not generally appreciated. The recent activity of oil companies in that State has attracted much attention, and in this paper themain structural and the general stratigraphic features are described. Fourfavorable areas are outlined. These contain folds of major interest. There areother favorable areas which have not been mapped.
Commercial pools discovered in this area would have the advantage of beingnear tidewater. Mobile, Ala., on the Gulf of Mexico, would be the logical sitefor refineries and shipping facilities. A pipe line could readily be laid tothat city from the Hatchitigbee and the Jackson areas. The logical outlet forthe Geneva and the Gordon areas would be Panama City, Fla., on the Gulf ofMexico.

Topography
The whole of the area under consideration lies in the Gulf coastal plain andslopes gently to the southwest and west. The elevations vary from 200 to 400ft. (60 to 121 m.) above sea level. The streams have sunk their channels intothis gently sloping plain, the main drainage flowing south or southwest intothe Gulf of Mexico. Between the streams are found remnants of this plain, constituting the hills of the area. The relief varies from a few feet up to 150ft. in certain parts. The country is generally covered by timber.

Stratigraphy
The thickness in the generalized sections presented must be consideredlargely as estimates, especially the thicknesses of the underlying Cretaceousbeds, as no wells have been drilled deep enough to give good type sections. TheCretaceous sections mentioned were secured at the outcrop and in water wells atshallow depths. Away from the old shoreline of the Cretaceous, it is verylikely that the beds thicken southward.
The comparative relations in Table 3 show the general correlation of theLouisiana and the Alabama formations.
AIME 059–46
Principles and Problems of Oil Prospecting in the Gulf Coast Country
Authors: Matteson W.G. 
Published: June 2014

Introduction

(a) Extent of the Gulf Coastal Plain
The Gulf Coastal plain of the southern United States is that area bordering forit large part the Gulf of Mexico and extending inland and northward to the main interior highland region. It is more or less V-shaped andincludes the States of Florida, extreme southern Alabama, all of Mississippi and Louisiana, the eastern and southern half of Arkansas, and the eastern, southeastern, and southern portions of Texas. While thecontents of this paper apply to the Gulf Coastal plain in general, they areintended to refer more specifically to that portion of the plain includedbetween the 90th and 97th meridians, and the 29th and 33d parallels, an area, that may be described geographically as comprising western Mississippi, all ofLouisiana, part of eastern and all of south-eastern Texas. It is within thisarea that numerous and prolific oil, pools have been developed during the last17 years.

(b) History of the Important Gulf Coast Oil Pools
Oil in commercial quantities was first found in the Gulf States atCorsicana, Tex., when, in 1896, a well was drilled into a sand, at 1030 ft. (313.9 m.) and came in at 22 bbl. daily production. Forty-seven wellsfollowed quickly thereafter, so that in 1897 this small pool had a yearlyproduction of 60,000 barrels.
Attention was first drawn to the Gulf Coastal region as a prolific source ofpetroleum, when, on Jan. 10, 1901, after several previous unsuccessful attemptsby other operators, Captain A. F. Lucas brought in Lucas No.1 at Spindletop, Tex., with an estimated initial flow of 40,000 to 75,000 bbl. daily, from asand at 1120 to 1139 ft. (341 to 347 m.). Although the productive area of thispool covers only 250 acres (101 ha.), it has yielded approximately 45,000,000bbl. of petroleum.
The Lucas well was epochal in that it demonstrated beyond question thepossibilities of the so-called salt domes as favorable reservoirs for theaccumulation of oil. Although the value of the professional petroleum geologistin locating favorable drilling territory had not been recognized at that time, operators with a keen sense of judgment and practicalturn of mind began an active investigation for salt domes.
Several, which had been recognized for some time, were leased and an activedrilling campaign instituted. Previous to the Lucas discovery, Savage Brothersattempted to develop the Sour Lake field, where several shallow wells weredrilled in 1894–95. The results of these tests were not stronglyencouraging.
AIME 059–47
Geology of Oil Fields of North Central Texas
Authors: Hager Dorsey 
Published: June 2014

North Central Texas has recently become a center of interest for the oil menof America. The bringing in of the McClosky well at Ranger, Eastland County, and the shallow pool at Brownwood, Brown County, in 1917, has stimulatedinterest in this area to fever pitch. Oil men from all over the United Statesare now investing there. The area of present interest is shown by theaccompanying map (Fig. 1).
The money spent in leases runs into millions of dollars. It is no exaggerationto say that a strip of country 200 miles (321 km.) long and 125 miles (201 km.)wide, comprising some 15,000,000 acres (6,070,310 ha.), has been leasedpractically solid at a cost for rentals and bonuses of at least $1 per acre.The test holes contracted for will certainly number 400, at a cost of at least $5,000,000. From what has been done in the past six months, $20,000,000 atleast will be spent. To pay returns on this amount of money, new production tothe extent of at least 12,000,000 bbl. must be obtained. At present, theproduction from new fields will not average over 5000 bbl. per day; three wellsat Ranger are producing 3000 bbl.; 250 wells at Brownwood produce 1000 bbl.;and the Gray well, Coleman County, is as yet an unknown factor.
However, at Ranger there is every indication of developing a good pool coveringfrom 1500 to 2000 acres (607 to 809 ha.), more or less, but the wells are deep,3400 to 3800 ft. (1036 to 1158 m.), and cost $35,000 to $40,000 to drill. Largewells are necessary to pay for such expensive holes. As new wells are drilled, the gas pressure will be lowered rapidly, and large production need not beexpected. For those oil men who expect a second Cushing or an Eldorado, Rangerholds little of promise.
At Brownwood, Brown County, there are some 250 shallow wells (depths from 200to 350 ft.) averaging 4 to 7 bbl. per day. There is a chance of an extensiveproducing area for these shallow sands to the southwest, and the opening ofseveral thousand acres of shallow oil territory, and also some promise ofdeeper oil horizons in the Ranger horizon, but probably all under 2500ft.
At present, the lease brokers and speculators, and only a handful of oil men, have made any money. More fields must be developed, and it is more particularlywith these possibilities that this paper deals. Lack of water for drillingpurposes has undoubtedly held back development so far this year; this part ofTexas has had a drought for two years and there is an actual scarcity ofwater.
AIME 061–47
Economic and Geologic Conditions Pertaining to Occurrence of Oil in North Argentine-Bolivian Field of South America
Authors: Herold Stanley C. 
Published: June 2014

Considerable interest has been shown, during recent years, in thepossibilities of developing oil fields in the South American Republics, nowthat the exhaustion of our present fields can be seen in the not very distantfuture. The demand for fuel oil and its products has been increasing far morerapidly than our increment of production during the last few years. Increase ofconsumption has been largely curtailed by the lack of sufficient supply. Themain factors that have contributed to our previous neglect of the southernfields have been as follows:Lack of sufficient demand for the product.Competition with producing fields, having large production, low cost, andbetter geographical position, such as Tampico, Mexico.Greater interest in home fields with ready market at hand.Our ignorance of southern economic and geologic conditions, due to thedistance between those areas and our financial centers.Economic conditions in the southern countries, necessitating high costs ofexploration and exploitation of the fields.Our lack of understanding of the business methods of the LatinAmerican.
It must be borne in mind that the oil-development work done to the present timein South America has, with one exception, been undertaken upon lands whichpossessed direct evidence of oil in seepages or asphaltic deposits, occurringeither immediately upon the lands or in their close vicinity. The developmentof oil fields in South America is therefore in the pioneer stage. It is not atall improbable that ?hidden fields? will be uncovered in future work, as hasoccurred notably in the mid-continental field of this country within recentyears.
AIME 061–49
Water Troubles in Mid-Continent Oil Fields, and their Remedies
Authors: Hager Dorsey , McPherson G.W. 
Published: June 2014

The rapid increase of water troubles in the Mid-Continent oil fields iscausing much alarm. Troubles occur at Towanda, Eldorado, Augusta, Cushing, Blackwell, and Healdton, although they had not been acute in the Mid-Continentfield until about two years ago, when the unusual conditions in the deeper oilfields were first encountered. California faced the same situation, but, thanksto aggressive measures, has largely overcome the dangers.
The following analysis of water trouble may throw some light on the subject andbe of assistance in solving the problems involved.
Water Troubles Classified
The presence of water in large quantities in oil sands has the following results:Diminishes oil production.Diminishes casing-head gasoline production:By curtailing the gas flow.By making the use of vacuum pumps unsuccessful.Increases lifting costs:By making it necessary to pump large quantities of water, which requires afast motion and long stroke (third hole).By requiring the use of compressors for air lift.By causing break-downs and delays due to the high speed necessary to pumpwater.By making it necessary to treat ?cut? or emulsified oil.
Oil production is seriously curtailed by the presence of large quantities ofwater. Lease records show that wells are shut down 40 to 60 per cent of thepumping time where serious water trouble occurs. While a small quantity of saltwater may cut the paraffin and keep the oil moving, several hundred feet, or ahole full of water, effectually ?kills? the oil and gas. The quick return ofwells to production, once the water is shut off, shows how wells have beenaffected.
AIME 061–51